Emerge Energy Services LP - FORM 10-Q

Attached files

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EX-32.2 - EXHIBIT 32.2 - Emerge Energy Services LP	a10q15630-q2xex322.htm
EX-32.1 - EXHIBIT 32.1 - Emerge Energy Services LP	a10q15630-q2xex321.htm
EX-31.1 - EXHIBIT 31.1 - Emerge Energy Services LP	a10q15630-q2xex311.htm
EX-31.2 - EXHIBIT 31.2 - Emerge Energy Services LP	a10q15630-q2xex312.htm
EX-95.1 - EXHIBIT 95.1 - Emerge Energy Services LP	a10q15630-q2ex951msha.htm

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

ý QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2015

¨ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission File No. 001-35912

EMERGE ENERGY SERVICES LP

(Exact name of registrant as specified in its charter)



Delaware		90-0832937
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

180 State Street, Suite 225, Southlake, Texas 76092		(817) 865-5830
(Address of principal executive offices)		(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:



Title of Each Class		Name of Each Exchange On Which Registered
Common Units Representing Limited Partner Interests		New York Stock Exchange

Securities registered pursuant to Section 12(g) of the Act: None

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. ý Yes o No

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). ý Yes o No

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer,” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one)



Large-Accelerated Filer x		Accelerated Filer o
Non-Accelerated Filer o		Smaller Reporting Company o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). o Yes ý No

As of July 29, 2015, 24,119,972 common units were outstanding.

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TABLE OF CONTENTS



		Page
	PART I – FINANCIAL INFORMATION

	Forward-Looking Statements	3

Item 1.	Financial Statements	4

	Unaudited Condensed Consolidated Balance Sheets as of June 30, 2015 and December 31, 2014	4

	Unaudited Condensed Consolidated Statements of Operations for the Three and Six Months Ended June 30, 2015 and 2014	5

	Unaudited Condensed Consolidated Statement of Partners’ Equity for the Six Months Ended June 30, 2015	6

	Unaudited Condensed Consolidated Statements of Cash Flows for the Six Months Ended June 30, 2015 and 2014	7

	Notes to Unaudited Condensed Consolidated Financial Statements	8

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	21

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	30

Item 4.	Controls and Procedures	30

	PART II – OTHER INFORMATION

Item 1.	Legal Proceedings	31

Item 1A.	Risk Factors	31

Item 4.	Mine Safety Disclosures	31

Item 6.	Exhibits	32

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FORWARD-LOOKING STATEMENTS

Certain statements and information in this Quarterly Report on Form 10-Q may constitute “forward-looking statements.” The words “believe,” “expect,” “anticipate,” “plan,” “intend,” “foresee,” “should,” “would,” “could” or other similar expressions are intended to identify forward-looking statements, which are generally not historical in nature. These forward-looking statements are based on our current expectations and beliefs concerning future developments and their potential effect on us. While management believes that these forward-looking statements are reasonable as and when made, there can be no assurance that future developments affecting us will be those that we anticipate. All comments concerning our expectations for future revenues and operating results are based on our forecasts for our existing operations and do not include the potential impact of any future acquisitions. Our forward-looking statements involve significant risks and uncertainties (some of which are beyond our control) and assumptions that could cause actual results to differ materially from our historical experience and our present expectations or projections. Important factors that could cause actual results to differ materially from those in the forward-looking statements include, but are not limited to, those summarized below:


•	failure to secure or maintain contracts with our largest customers, or non-performance of any of those customers under the applicable contract;


•	competitive conditions in our industry;


•	the amount of frac sand we are able to excavate and process, which could be adversely affected by, among other things, operating difficulties and unusual or unfavorable geologic conditions;


•	the volume of frac sand we are able to sell;


•	the price at which we are able to sell frac sand;


•	changes in the long-term supply of and demand for oil and natural gas;


•	volatility of fuel prices;


•	unanticipated ground, grade or water conditions at our sand mines;


•	actions taken by our customers, competitors and third-party operators;


•	our ability to complete growth projects on time and on budget;


•	increasing costs and minimum contractual obligations relating to our transportation services and infrastructure;


•	inclement or hazardous weather conditions, including flooding, and the physical impacts of climate change;


•	environmental hazards;


•	industrial accidents;


•	changes in laws and regulations (or the interpretation thereof) related to the mining and hydraulic fracturing industries, silica dust exposure or the environment;


•	inability to acquire or maintain necessary permits or mining or water rights;


•	facility shutdowns in response to environmental regulatory actions;


•	inability to obtain necessary production equipment or replacement parts;


•	reduction in the amount of water available for processing;


•	technical difficulties or failures;


•	labor disputes and disputes with our excavation contractor;


•	late delivery of supplies;


•	difficulty collecting receivables;


•	inability of our customers to take delivery of our products;


•	changes in the price and availability of transportation;


•	fires, explosions or other accidents;


•	pit wall failures or rock falls;


•	the effects of future litigation; and


•	other factors discussed in this Quarterly Report on Form 10-Q and the detailed factors discussed under the heading “Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2014.

When considering forward-looking statements, you should keep in mind the known material risk factors and other cautionary statements set forth in our Annual Report on Form 10-K for the year ended December 31, 2014 in “Risk Factors” and in this Form 10-Q in “Management’s Discussion and Analysis of Financial Condition and Results of Operations.” Readers are cautioned not to place undue reliance on forward-looking statements, which speak only as of the date hereof. We undertake no obligation to publicly update or revise any forward-looking statements after the date they are made, whether as a result of new information, future events or otherwise.

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PART I FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

EMERGE ENERGY SERVICES LP

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS

($ in thousands, except unit data)



	June 30, 2015		December 31, 2014
ASSETS
Current assets:
Cash and cash equivalents	$	3,241	$	6,876
Trade and other receivables, net	59,785		75,708
Inventories	41,619		32,278
Prepaid expenses and other current assets	12,317		9,262
Total current assets	116,962		124,124

Property, plant and equipment, net	233,266		238,657
Intangible assets, net	27,684		31,158
Goodwill	29,264		29,264
Other assets, net	12,086		8,924
Total assets	$	419,262	$	432,127

LIABILITIES AND PARTNERS’ EQUITY
Current liabilities:
Accounts payable	$	26,548	$	21,341
Accrued liabilities	17,345		24,411
Current portion of long-term debt	—		53
Current portion of capital lease liability	155		930
Total current liabilities	44,048		46,735

Long-term debt, net of current portion	249,142		217,023
Business acquisition obligation, net of current portion	10,311		10,737
Capital lease liability, net of current portion	—		57
Other long-term liabilities	3,763		2,386
Total liabilities	307,264		276,938

Commitments and contingencies
Partners’ equity:
General partner	—		—
Limited partner common units (issued and outstanding 24,119,972 units and 23,718,961 units as of June 30, 2015 and December 31, 2014, respectively)	111,998		155,189
Total partners’ equity	111,998		155,189
Total liabilities and partners’ equity	$	419,262	$	432,127

See accompanying notes to unaudited condensed consolidated financial statements.

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EMERGE ENERGY SERVICES LP

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

($ in thousands, except unit and per unit data)



	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014
Revenues (1)	$	200,852		$	298,273		$	404,813		$	572,354
Operating expenses:
Cost of goods sold (excluding depreciation, depletion and amortization) (1)	176,933			261,395			345,263			501,191
Depreciation, depletion and amortization	7,355			5,711			13,795			11,481
Selling, general and administrative expenses	8,179			8,994			17,782			17,469
Project termination	2,693			—			9,412			—
Total operating expenses	195,160			276,100			386,252			530,141
Operating income	5,692			22,173			18,561			42,213

Other expense (income):
Interest expense, net	2,632			1,943			5,761			3,527
Other	(15		)	(32		)	(44		)	(151		)
Total other expense	2,617			1,911			5,717			3,376
Income before provision for income taxes	3,075			20,262			12,844			38,837
Provision for income taxes	191			170			469			259
Net income	$	2,884		$	20,092		$	12,375		$	38,578

Earnings per common unit (basic) (2)	$	0.12		$	0.84		$	0.51		$	1.61
Earnings per common unit (diluted) (2)	$	0.12		$	0.83		$	0.51		$	1.60

Weighted average number of common units outstanding including participating securities (basic) (2)	24,131,302			24,031,650			24,129,664			24,023,651
Weighted average number of common units outstanding (diluted) (2)	24,133,813			24,112,954			24,131,682			24,068,178

(1) Fuel revenues and cost of goods sold include excise taxes and similar taxes:	$	12,520		$	13,292		$	24,315		$	25,197
(2) See Note 8.

See accompanying notes to unaudited condensed consolidated financial statements.

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EMERGE ENERGY SERVICES LP

UNAUDITED CONDENSED CONSOLIDATED STATEMENT OF PARTNERS’ EQUITY

($ in thousands)



	Limited Partner Common Units			General Partner (non-economic interest)		Total Partners’ Equity
Balance at December 31, 2014	$	155,189		$	—	$	155,189
Net income	12,375			—		12,375
Equity-based compensation expense	3,076			—		3,076
Distributions paid	(58,150		)	—		(58,150		)
Distribution equivalent rights accrued	(492		)	—		(492		)
Balance at June 30, 2015	$	111,998		$	—	$	111,998

See accompanying notes to unaudited condensed consolidated financial statements.

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EMERGE ENERGY SERVICES LP

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

($ in thousands)



	Six Months Ended June 30,
	2015			2014
Cash flows from operating activities:
Net income	$	12,375		$	38,578
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	13,795			11,481
Equity-based compensation expense	3,227			4,330
Project termination costs - non-cash portion	8,684			—
Provision for doubtful accounts	296			63
Loss on disposal of assets	8			19
Amortization of debt discount/premium and deferred financing costs	557			426
Unrealized loss on derivative instruments	389			633
Other non-cash	39			10
Changes in operating assets and liabilities, net of business acquired:
Restricted cash and equivalents	—			6,188
Accounts receivable	22,705			(31,124		)
Inventories	(9,341		)	8,811
Prepaid expenses and other current assets	(3,055		)	(9,076		)
Accounts payable and accrued liabilities	(6,605		)	(757		)
Other assets	(3,161		)	(4		)
Net cash provided by operating activities	39,913			29,578

Cash flows from investing activities:
Purchases of property, plant and equipment	(16,596		)	(30,856		)
Proceeds from disposals of assets	1,046			245
Collection of notes receivable	7			6
Deposit for business acquisition	—			(11,000		)
Net cash used in investing activities	(15,543		)	(41,605		)

Cash flows from financing activities:
Proceeds from line of credit borrowings	162,400			167,057
Repayment of line of credit borrowings	(130,400		)	(90,903		)
Repayment of other long-term debt	(53		)	(168		)
Distributions to unitholders	(58,164		)	(51,481		)
Payment of business acquisition obligation	(518		)	—
Payments on capital lease obligation	(832		)	(724		)
Payment of financing costs	(438		)	(2,330		)
Other financing activities	—			11
Net cash provided by (used in) financing activities	(28,005		)	21,462

Cash and cash equivalents:
Net increase (decrease)	(3,635		)	9,435
Balance at beginning of period	6,876			2,167
Balance at end of period	$	3,241		$	11,602

See accompanying notes to unaudited condensed consolidated financial statements.

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EMERGE ENERGY SERVICES LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. ORGANIZATION AND BASIS OF PRESENTATION

Organization

Emerge Energy Services LP (“Emerge”) is a Delaware limited partnership that completed its initial public offering (“IPO”) on May 14, 2013 to become a publicly traded partnership. The combined entities of Superior Silica Sands LLC (“SSS”), a Texas limited liability company, Allied Energy Company LLC (“AEC”), an Alabama limited liability company, and Emerge Energy Services Operating LLC (“Emerge Operating”), a Delaware limited liability company, represent the predecessor for accounting purposes (the “Predecessor”) of Emerge. Emerge acquired Direct Fuels LLC (“Direct Fuels”) in a business combination concurrent with the IPO on May 14, 2013,

References to the “Partnership,” “we,” “our” or “us” when used for dates or periods ended prior to the IPO, refer collectively to the Predecessor. References to the “Partnership,” “we,” “our” or “us” when used for dates or periods ended on or after the IPO, refer collectively to Emerge and all of its subsidiaries, including Direct Fuels.

We are a growth-oriented energy services company engaged in: (i) the business of mining, producing, and distributing silica sand that is a key input for the hydraulic fracturing of oil and gas wells; and, (ii) the business of distributing refined motor fuels, refining transportation mixture (“transmix”) and biodiesel, operating bulk motor fuel storage terminals, and providing complementary services. We report silica sand activities through the Sand segment and motor fuel operations through the Fuel segment. We report items of income (if any) and expense that cannot be directly associated with the Sand and Fuel segments as “corporate.”

The Sand segment conducts mining and processing operations from facilities located in Wisconsin and Texas. In addition to mining and processing silica sand for the oil and gas industry, the Sand segment sells its product for use in building products and foundry operations. The Fuel segment operates transmix processing facilities located in the Dallas-Fort Worth area and in Birmingham, Alabama. The Fuel segment also offers third-party bulk motor fuel storage and terminal services, biodiesel refining, sale and distribution of wholesale motor fuels, reclamation services (which consists primarily of cleaning bulk storage tanks used by other petroleum terminal and others) and blending of renewable fuels.

Secondary Offering

On June 20, 2014, we and our general partner, along with certain selling unitholders named therein (the “Selling Unitholders”) entered into an Underwriting Agreement with underwriters named therein (the “Underwriters”), with respect to the offer and sale (the “Secondary Offering”) by the Selling Unitholders of 3,515,388 common units at a price to the public of $109.06 per common unit ($105.2429 per common unit, net of underwriting discounts and commissions). On June 25, 2014, the Selling Unitholders completed the Secondary Offering. We did not receive any proceeds from the Secondary Offering. Pursuant to the Underwriting Agreement, the Selling Unitholders also granted the Underwriters an option for a period of 30 days to purchase up to an additional 527,307 common units on the same terms, and on July 18, 2014, the Underwriters partially exercised the option to purchase 165,635 common units. Following the closing of this transaction and as of June 30, 2015, Insight Equity Management Company LLC and its affiliated investment funds and its controlling equity owners (collectively “Insight Equity”) held approximately 30% of all of our outstanding common units.

Basis of Presentation and Consolidation

The accompanying unaudited condensed consolidated financial statements were prepared using generally accepted accounting principles for interim financial information and the instructions to Form 10-Q and Regulation S-X. Accordingly, these financial statements do not include all information or notes required by generally accepted accounting principles for annual financial statements and should be read together with our 2014 Annual Report on Form 10-K. These financial statements include the accounts of all of our subsidiaries. All significant intercompany transactions and balances have been eliminated in consolidation.

Acquisition from Midwest

On July 25, 2014, we acquired certain assets and obligations of Midwest Frac and Sands LLC (“Midwest”) in order to expand access to high quality sand reserves near our Wisconsin processing plants, improve earnings, and exert greater control over our sand feedstock supply. Midwest operated a sand mine and wet wash facility in Barron County, Wisconsin. The assets include, but are not limited to, mineral reserves, real estate, buildings, land improvements, wet wash processing and conveying equipment, fixtures and office equipment, permits, and a non-compete agreement with the seller. The liabilities assumed include accounts payable and a local government highway repair and maintenance agreement. We have accounted for the acquisition as a business combination under Financial Accounting Standards Board Accounting Standards Codification (“FASB ASC”) 805, Business Combinations.

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The purchase agreement specifies a total cash purchase price of $24.0 million plus contingent consideration, if any. The agreement required an advance payment of $11.0 million in June 2014. The additional $13.0 million is being paid over time as sand is removed from the reserves, with a minimum of $2.0 million paid each year. After repayment of $13.0 million, we will continue to pay contingent consideration for any additional sand we remove, for as long as the sand reserves remain economically viable. We used a discounted cash flow analysis to estimate the present value of the contingent consideration and other liabilities assumed as of the purchase date, using management’s estimates of the volumes and timing of sand extraction. We estimate that the entire obligation will be repaid within 7 - 8 years after acquisition, assuming production of approximately 850,000 tons of wet washed sand per year. The seller can repurchase the land when we determine the property is no longer viable for our sand mining and processing activities.

As part of the agreement, we cancelled an existing tolling agreement whereby we agreed to convert Midwest’s wet washed sand to dry sand as well as an existing supply contract whereby Midwest agreed to supply and deliver wet washed sand. We recorded a $0.7 million loss on settlement of pre-existing agreements as a component of “Other” expense on our Condensed Consolidated Statements of Operations. We estimated the fair values of the terminated agreements using a discounted cash flow analysis.

We retained a third-party expert to assist in determining the volumes and quality of the in-place mineral reserves. With assistance from a third-party valuations expert, we then used this data in our determination of the fair values of identifiable net assets, using the income approach. Our assessment of the fair values of the assets acquired and liabilities assumed as of July 25, 2014 indicates that there was no goodwill associated with the acquisition. We recognized the assets acquired and liabilities assumed based upon the fair values determined on the date of acquisition, using significant inputs that are not observable in the market (i.e., Level 3 inputs). Such values are preliminary and may be revised as we complete our analysis of the fair values of the assets acquired and liabilities assumed, but will be finalized no later than one year from the acquisition date.

Following is a reconciliation of the total consideration to the assets acquired and liabilities assumed as of the acquisition date ($ in thousands):



Consideration:
Cash deposit	$	11,000
Present value of purchase obligation	11,226
Present value of contingent consideration	853
Loss on settlement of pre-existing agreements	(689		)
Total consideration	$	22,390

Assets acquired:
Mineral reserves	$	19,381
Other property, plant and equipment	4,403
Non-compete agreement	100
Total assets acquired	23,884
Less liabilities assumed:
Governmental highway improvement obligation	1,128
Asset retirement obligation	227
Accounts payable	139
Net assets acquired	$	22,390

In our Condensed Consolidated Balance Sheets, we have classified the non-current portion of the purchase obligation in “Business acquisition obligation, net of current portion.” The governmental highway improvement obligation and the current portion of the purchase obligation are classified as “Accrued liabilities.”

We incurred approximately $0.1 million in transaction costs, which were recorded as “Selling, general and administrative expenses” as incurred.

The historical financial information for the assets acquired was impractical to obtain, and inclusion of pro forma information would require us to make estimates and assumptions regarding these assets’ historical financial results that may not be reasonable or accurate. As a result, supplemental pro forma results are not presented. This acquisition is not expected to impact our consolidated revenues. It is impractical to determine net income included in our consolidated statements of operations relating to Midwest since the date of acquisition because Midwest has been fully integrated into our sand segment operations and the operating results. For this reason, the operating results of Midwest cannot be separately identified.

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Reclassifications

Certain reclassifications have been made to prior period amounts to conform to the current period presentation. These reclassifications do not impact net income and do not reflect a material change in the information previously presented in our Condensed Consolidated Statements of Operations.

2. OTHER FINANCIAL DATA

Restricted Cash and Equivalents

We were required under agreements with our chief executive officer (“CEO”) and an officer in our Sand segment (the “Sand Officer”) to establish and maintain Rabbi Trusts which were used to fund deferred compensation as described in the agreements. Restricted cash and equivalents were invested in short-term instruments at market rates; therefore the carrying values approximated fair value. In May 2014, all funds in the Rabbi Trusts were distributed to our CEO and Sand Officer and the Rabbi Trusts were terminated.

Allowance for Doubtful Accounts

The allowance for doubtful accounts was $0.7 million and $0.4 million at June 30, 2015 and December 31, 2014, respectively.

Inventories

Inventories consisted of the following:



	June 30, 2015		December 31, 2014
	($ in thousands)
Sand finished goods	$	13,234	$	7,582
Sand work in process	12,187		14,413
Refined fuels	10,413		8,031
Fuel raw materials and supplies	5,712		2,157
Sand raw materials and supplies	73		95
Total	$	41,619	$	32,278

Property, Plant and Equipment

Property, plant and equipment consisted of the following:



	June 30, 2015		December 31, 2014
	($ in thousands)
Machinery and equipment (1)	$	151,169	$	146,951
Buildings and improvements (1)	55,143		51,027
Land and improvements (1)	40,365		37,461
Mineral reserves	30,181		30,181
Construction in progress	17,751		24,172
Capitalized reclamation costs	2,445		2,332
Total cost	297,054		292,124
Accumulated depreciation and depletion	63,788		53,467
Net property, plant and equipment	$	233,266	$	238,657

(1) Includes assets under capital lease

We recognized $10.3 million and $7.3 million of depreciation and depletion expense for the six months ended June 30, 2015 and 2014, respectively.

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Intangible Assets Other Than Goodwill

Our intangible assets other than goodwill consisted of the following:



	Cost		Accumulated Amortization		Net
	($ in thousands)
June 30, 2015:
Trade names	$	46	$	22	$	24
Customer relationships	43,922		18,280		25,642
Supply and transportation agreements	3,330		2,067		1,263
Non-compete agreement	1,550		795		755
Total	$	48,848	$	21,164	$	27,684

December 31, 2014:
Trade names	$	46	$	20	$	26
Customer relationships	43,922		15,293		28,629
Supply and transportation agreements	3,330		1,769		1,561
Non-compete agreement	1,550		608		942
Total	$	48,848	$	17,690	$	31,158

We recognized $3.5 million and $4.2 million of amortization expense for the six months ended June 30, 2015 and 2014, respectively.

Other Assets, Net

Other assets, net consisted of the following:



	June 30, 2015		December 31, 2014
	($ in thousands)
Prepaid lease assets, net of current portion*	$	11,392	$	8,333
Other	694		591
Total	$	12,086	$	8,924


*	The cost to transport leased railcars from the manufacturer to our site for initial placement in service is capitalized and amortized over the term of the lease (typically five to seven years). This balance reflects the non-current portion of these capitalized costs.

Accrued Liabilities

Accrued liabilities consisted of the following:



	June 30, 2015		December 31, 2014
	($ in thousands)
Sales, excise, property and income taxes	$	5,220	$	5,002
Current portion of business acquisition obligations	2,378		2,702
Logistics	2,000		3,185
Deferred compensation	1,672		1,341
Salaries and other employee-related	1,346		4,048
Derivative contract liability	811		422
Current portion of contract termination	440		—
Maintenance	393		—
Sand purchases and royalties	325		659
Construction	315		3,379
Other	2,445		3,673
Total	$	17,345	$	24,411

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Mining and Wet Sand Processing Agreement

In April 2014, a five-year contract with a sand processor (“Processor”) became effective to support our sand business in Wisconsin. Under this contract, the Processor financed and built a wet wash processing plant near our Wisconsin operations. As part of the agreement, the Processor wet washes our sand, creates stockpiles of washed sand and maintains the plant and equipment. During the term of the agreement the Processor will own the wet plant along with the equipment and other temporary structures used to support this activity. At the end of the five-year term of the agreement or following a default under the contract by the Processor, we have the right to take ownership of the wet plant and other equipment without charge. Subject to certain conditions, ownership of the plant and equipment will transfer to us at the expiration of the term. We accounted for the wet plant as a capital lease obligation. The original capitalized lease asset and corresponding capital lease obligation totaled $3.3 million.

Project Termination

In 2014, we began development of sand processing facilities in Independence, Wisconsin. Due to a number of complications, such as an increase in projected operating costs and a decline in the market price and demand for frac sand in early 2015, we determined that this project was no longer economically viable. As of June 30, 2015, we have recorded an $8.0 million charge to earnings for non-recoverable costs incurred for this project to-date, including items such as engineering, legal and other professional service fees, site preparation costs, and writedowns of assets to estimated net realizable value. We may adjust this estimate in the future as certain contingencies are resolved, but we do not expect any such adjustments to be significant.

Management committed to a plan to discontinue this project in April 2015. In accordance with FASB ASC 420, Exit or Disposal Cost Obligations, any contract termination charges and estimated values of continuing contractual obligations for which we will receive no future value will be recognized as a charge to earnings as of the contract termination date or cease-use date. We currently estimate these contract termination charges will be approximately $1.4 million, which were accrued in the three months ended June 30, 2015. These liabilities will be reviewed periodically and may be adjusted when necessary, but we do not expect any such adjustments to be significant.

The following table illustrates the exit and disposal reserves related to the termination of the Independence, Wisconsin project included in Accrued liabilities and Other long-term liabilities in our Condensed Consolidated Balance Sheets:



	($ in thousands)
Balance at December 31, 2014	$	—
Contract termination charges	1,352
Interest	10
Payments	—
Balance at June 30, 2015	$	1,362

Fair Value of Financial Instruments

Our financial instruments consist primarily of cash and cash equivalents, restricted cash and equivalents, accounts receivable, accounts payable and debt instruments. The carrying amounts of cash and cash equivalents, restricted cash and cash equivalents, accounts receivable and accounts payable are representative of their fair values due to their short maturities. The carrying amounts of our revolving credit facility approximates fair value because the underlying instrument includes provisions that adjust our interest rates based on current market rates.

Retirement Plan

We sponsor a 401(k) plan for substantially all employees that provides for us to match 100% of participant contributions up to 5% of the participant’s pay. Additionally, we can make discretionary contributions as deemed appropriate by management. Our employer contributions to these plans totaled $0.5 million and $0.3 million for the six months ended June 30, 2015 and 2014, respectively.

Seasonality

For our Sand segment, winter weather affects the months during which we can wash and wet-process sand in Wisconsin. Seasonality is not a significant factor in determining our ability to supply sand to our customers because we accumulate a stockpile of wet sand feedstock during non-winter months. During the winter, we process the stockpiled sand to meet customer requirements. However, we sell sand for use in oil and natural gas production basins where severe weather conditions may curtail drilling activities. This is particularly true in drilling areas located in the northern U.S. and western Canada. If severe winter weather precludes drilling activities, our frac sand sales volume may be adversely affected. Generally, severe weather episodes affect production in the first quarter with effects possibly continuing into the second quarter. Generally, our Fuel segment does not experience dramatic seasonal shifts in quantities delivered to its customers.

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Concentration of Credit Risk

We provide credit, in the normal course of business, to customers located throughout the United States and Canada. We perform ongoing credit evaluations of our customers and generally do not require collateral. In addition, we regularly evaluate our credit accounts for loss potential.

Our two largest customer balances represented 14% and 13% of our net accounts receivable balance as of June 30, 2015. On December 31, 2014, our two largest customers represented 24% and 15% of our net accounts receivable balance. No other customer balance exceeded 10% of the total net accounts receivable balance as of June 30, 2015 and December 31, 2014.

One customer represented 10% of total revenues for the six months ended June 30, 2015, while a different customer represented 11% of revenues for the six months ended June 30, 2014.

Recent Accounting Pronouncements

In May 2014, the FASB issued Accounting Standards Update (“ASU”) 2014-09, Revenue from Contracts with Customers, as a new Topic, Accounting Standards Codification Topic 606. The new revenue recognition standard provides a five-step analysis of transactions to determine when and how revenue is recognized. The core principle is that a company should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. This guidance is effective for annual periods beginning after December 15, 2016 and shall be applied retrospectively to each period presented or as a cumulative-effect adjustment as of the date of adoption. On July 9, 2015, the FASB deferred, by one year, the effective date to annual reporting periods beginning after December 15, 2017. The proposed new effective date guidance will allow early adoption for all entities (i.e., both public business entities and other entities) as of the original effective date for public business entities, which was annual reporting periods beginning after December 15, 2016, and the interim periods within that year. Early adoption by public business entities was not permitted under the original effective date guidance. We are evaluating the effect of adopting this new accounting guidance but do not expect adoption will have a material impact on our financial position, results of operations or cash flows.

In April 2015, the FASB issued ASU No. 2015-03, Interest—Imputation of Interest, to modify the presentation of debt issuance costs. Under ASU 2015-03 debt issuance costs are required to be presented as a direct deduction of debt balances on the statement of financial position, similar to the presentation of debt discounts. ASU 2015-03 is effective for public companies for years beginning after December 15, 2015, and interim periods within those fiscal periods. For all other entities, ASU 2015-03 is effective for years beginning after December 15, 2015 and interim periods within annual periods beginning after December 15, 2016. Early adoption is permitted for financial statements that have not already been issued. Additionally, the provisions should be applied on a retrospective basis as a change in accounting principle. We adopted ASU 2015-03 as of March 31, 2015. The adoption of this new accounting guidance resulted in a reclassification of deferred financing costs from “Other assets, net” to “Long-term debt, net of current portion” on our condensed consolidated balance sheets for the current and all prior periods. There was no impact on our results of operations or cash flows.

In July 2015, the FASB issued ASU 2015-11, Simplifying the Measurement of Inventory. Under this ASU, inventory will be measured at the lower of cost and net realizable value and options that currently exist for market value will be eliminated. The ASU defines net realizable value as the estimated selling prices in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation. No other changes were made to the current guidance on inventory measurement. ASU 2015-11 is effective for interim and annual periods beginning after December 15, 2016. Early application is permitted and should be applied prospectively. We are evaluating the effect of adopting this new accounting guidance but do not expect adoption will have a material impact on our financial position, results of operations or cash flows.

3. LONG-TERM DEBT

Following is a summary of our long-term debt:



	June 30, 2015			December 31, 2014
	($ in thousands)
Revolving credit facility:
Principal	$	253,864		$	221,864
Deferred financing costs	(4,722		)	(4,841		)
Other notes	—			53
Total debt	249,142			217,076
Less current portion	—			53
Long-term portion	$	249,142		$	217,023

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Revolving Credit Facility

On May 14, 2013, we entered into a $150 million revolving credit and security agreement (as amended and restated, the “Credit Agreement”) among Emerge Energy Services LP, as parent guarantor, each of its subsidiaries, as borrowers (the “Borrowers”), and PNC Bank, National Association, as administrative agent and collateral agent. Substantially all of the assets of the Borrowers are pledged as collateral under the Credit Agreement.

On December 10, 2013, we amended the Credit Agreement to revise certain definitions and to increase the commitment amount for our revolving loan credit facility to $200 million.

On June 27, 2014, we amended and restated the Credit Agreement to:


•	increase our revolving credit facility (the “Credit Facility”) to $350 million, which we may increase from time to time upon our satisfaction of certain conditions by up to an aggregate of $150 million;


•	revise the interest rates applicable to borrowings under the Credit Facility as follows (at our option);


•	a Base Rate (as defined in the Credit Agreement), which will be the base commercial lending rate of PNC Bank, as publicly announced to be in effect from time to time, plus an applicable margin ranging from 1.25% to 2% based on our total leverage ratio; or


•	LIBOR plus an applicable margin ranging from 2.25% to 3% based on our total leverage ratio;


•	increase the sublimit for the issuance of letters of credit to $30 million;


•	revise financial covenants as discussed below; and


•	extend the maturity date to June 27, 2019.

We also incur a commitment fee of 0.375% on committed amounts that are neither used for borrowings nor under letters of credit.

The Credit Agreement contains various covenants and restrictive provisions and requires maintenance of financial covenants as follows:


•	an interest coverage ratio (as defined in the Credit Agreement) of not less than 3.00 to 1.00; and


•	a total leverage ratio (as defined in the Credit Agreement) of not greater than 3.00 to 1.00. On April 6, 2015, we entered into an amendment to the Credit Agreement that increased this leverage ratio to 3.50 to 1.00.

At June 30, 2015, we were in compliance with our loan covenants and had undrawn availability under the Credit Facility totaling $86.8 million. At June 30, 2015, our outstanding borrowings under the Credit Agreement bore interest at a weighted-average rate of 3.10%.

4. COMMITMENTS AND CONTINGENCIES

Contractual Obligations

The following table represents the remaining minimum contractual obligations as of June 30, 2015.



	Railcar Leases (1)		Other Operating Leases (2)		Royalty Commitments (3)		Purchase Commitments (4)			Capital Lease Obligations

	($ in thousands)
Remainder of 2015	$	28,645	$	1,343	$	240	$	19,173		$	157
2016	58,054		1,422		480		33,228			—
2017	54,500		861		480		33,004			—
2018	57,678		505		480		29,777			—
2019	63,042		334		480		28,254			—
Thereafter	228,457		2,842		6,210		89,210			—
Total	$	490,376	$	7,307	$	8,370	232,646			157
Less amount representing interest							(1,753		)	(2		)
Total less interest							$	230,893		$	155


(1)	Includes minimum amounts payable under various operating leases for railcars as well as estimated costs to transport leased railcars from the manufacturer to our site for initial placement in service.


(2)	Includes lease agreements for land, facilities and equipment.


(3)	Represents minimum royalty payments for various sand mining locations. The amounts paid will differ based on amounts extracted.


(4)	Includes minimum amounts payable under a business acquisition agreement, long-term rail transportation agreements, and other purchase commitments.

Excise Tax Penalty

In 2012, we received an IRS notice of a penalty totaling $340,000 due to failure to file terminal operator reports in electronic format. We filed these returns in paper format. Management protested the audit findings through IRS appeal channels. On May 29, 2015, IRS offered to reduce the penalty to $50,000 which we accepted and paid on June 9, 2015.

Environmental Matter

On November 21, 2013, the EPA issued a General Notice Letter and Information Request (“Notice”) under Section 104(e) of the Comprehensive Environmental Response, Compensation, and Liability Act of 1980, as amended (“CERCLA”), to one of our subsidiaries operating within the Fuel segment. The Notice provides that the subsidiary may have incurred liability with respect to the Reef Environmental site in Alabama, and requested certain information in accordance with Section 107(a) of CERCLA. We timely responded to the Notice. At this time, no specific claim for cost recovery has been made by the EPA (or any other potentially responsible party) against us. There is uncertainty relating to our share of environmental remediation liability, if any, because our allocable share of wastewater is unknown and the total remediation cost is also unknown. Consequently, management is unable to estimate the possible loss or range of loss, if any. We have not recorded a loss contingency accrual as of June 30, 2015 or December 31, 2014. In the opinion of management, the outcome of such matters will not have a material adverse effect on our financial position, liquidity or results of operations.

5. RELATED PARTY TRANSACTIONS

Related party transactions included in our Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Operations are summarized in the following table:



	Six Months Ended June 30,
	2015		2014
	($ in thousands)
Wages and employee-related costs (1)	$	16,032	$	13,677
General and administrative expense reimbursements (2)	$	—	$	75
Lease expense	$	13	$	13



	June 30, 2015		December 31, 2014
	($ in thousands)
Accounts receivable	$	223	$	181
Accounts payable and accrued liabilities	$	588	$	704


(1)	We do not have any employees. Our general partner manages our human resource assets, including fringe benefits and other employee-related charges. We routinely and regularly reimburse our general partner for any employee-related costs paid on our behalf, and report such costs as operating expenses.


(2)	We paid Insight Equity certain general and administrative costs.

6. EQUITY-BASED COMPENSATION

Effective May 14, 2013, we adopted our 2013 Long-Term Incentive Plan (the “LTIP”) for providing long-term incentives for employees, directors, and consultants who provide services to us, and provides for the issuance of an aggregate of up to 2,321,968 common units to be granted either as options, restricted units, phantom units, distribution equivalent rights, unit appreciation rights, unit award, profits interest units, or other unit-based award granted under the plan. All of our outstanding grants will be settled through issuance of limited partner common units.

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On May 14, 2013, we granted 530,588 and 265,294 phantom units to our CEO and Sand Officer, respectively. Half of these phantom units vested after one year, and the remaining half vested on May 14, 2015. For phantom units granted to employees in 2013, we currently assume a 43-month vesting period, which represents management’s estimate of the amount of time until all vesting conditions have been met. Concurrent with the closing of a secondary offering in June 2014 and the exercise of the underwriters’ over-allotment in July 2014, 90,686 of these phantom units vested and common units were issued. For other phantom units granted to employees, we assume a 36 to 48-month vesting period. Restricted units are awarded to our independent directors on each anniversary of our IPO, each with a vesting period of one year. Regarding distributions for independent directors and other employees, distributions are credited to a distribution equivalent rights account for the benefit of each participant and become payable generally within 45 days following the date of vesting. As of June 30, 2015, the unpaid liability for distribution equivalent rights totaled $1.7 million.

The following table summarizes awards granted during the six months ended June 30, 2015.



	Total Units		Phantom Units		Restricted Units		Fair Value per Unit at Award Date
Outstanding at December 31, 2014	605,664		602,836		2,828		$	18.12
Granted	24,925		14,438		10,487		43.5
Vested	(401,011	)	(397,941	)	(3,070	)	17.50
Forfeitures	(5,815	)	(5,815	)	—		113.16
Outstanding at June 30, 2015	223,763		213,518		10,245		$	19.58

For the six months ended June 30, 2015 and 2014, we recorded non-cash compensation expense relating to equity-based compensation of $3.2 million and $4.3 million, respectively, in selling, general and administrative expenses. As of June 30, 2015, the unrecognized compensation expense related to the grants discussed above amounted to $2.6 million to be recognized over a weighted average of 1.55 years.

7. INCOME TAXES

Provision for Income Taxes

Our provision for income taxes relates to: (i) Texas margin taxes for the Partnership and for Emerge Energy Distributors Inc. (“Distributor”), (ii) federal and state income taxes for Distributor, and (iii) an insignificant amount of Canadian income taxes on SSS earnings in Canada (most of our earnings are exempted under a U.S/Canada tax treaty). For federal income tax purposes, we report our income, expenses, gains, and losses as a partnership not subject to income taxes. As such, each partner is responsible for his or her share of federal and state income tax. Net earnings for financial statement purposes may differ significantly from taxable income reportable to each partner because of differences between the tax basis and financial reporting basis of assets and liabilities. Distributor reports its income, expenses, gains, and losses as a corporation and is subject to both federal and state income taxes.

The composition of our provision for income taxes follows:



	Six Months Ended June 30,
	2015		2014
	($ in thousands)
Federal and state income tax expense for Distributor	$	201	$	181
Texas margin tax	250		78
Canadian income tax	18		—
Total provision for income taxes	$	469	$	259

Effective Income Tax Rate

Distributor began operations in May 2013. For the six months ended June 30, 2015, Distributor’s effective income tax rate was 35%. For Distributor, there were no significant differences between book and taxable income. We are responsible for our portion of the Texas margin tax that is included in our subsidiaries’ consolidated Texas franchise tax returns. For our operations in Texas, the effective margin tax rate is approximately 0.975% as defined by applicable state law. The margin tax qualifies as an income tax under GAAP, which requires us to recognize the impact of this tax on the temporary differences between the financial statement assets and liabilities and their tax basis attributable to such tax.

8. EARNINGS PER COMMON UNIT

We compute basic earnings per unit by dividing net income by the weighted-average number of common units outstanding including participating securities. Participating securities include unvested equity-based payment awards that contain non-forfeitable rights to distributions.

Diluted earnings per unit is computed by dividing net income by the weighted-average number of common units outstanding, including participating securities, and increased further to include the number of common units that would have been outstanding had potential dilutive units been exercised. The dilutive effect of restricted units is reflected in diluted net income per unit by applying the treasury stock method. Under FASB ASC 260-10-45, Contingently Issuable Shares, 201,080 of our outstanding phantom units are not included in basic or diluted earnings per common unit calculations as of June 30, 2015. At June 30, 2015, there were no anti-dilutive units outstanding.

Basic and diluted earnings per unit are computed as follows:



	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
	($ in thousands, except per unit data)
Net Income	$	2,884	$	20,092	$	12,375	$	38,578

Basic earnings per unit:
Weighted average common units outstanding	23,930,483		23,445,671		23,825,306		23,333,300
Weighted average phantom units deemed participating securities	200,819		585,979		304,358		690,351
Total	24,131,302		24,031,650		24,129,664		24,023,651
Earnings per common unit (basic)	$	0.12	$	0.84	$	0.51	$	1.61

Diluted earnings per unit:
Weighted average common units outstanding	23,930,483		23,521,808		23,825,306		23,371,340
Weighted average phantom units deemed participating securities	200,819		585,979		304,358		690,351
Weighted average potentially dilutive units outstanding	2,511		5,167		2,018		6,487
Total	24,133,813		24,112,954		24,131,682		24,068,178
Earnings per common unit (diluted)	$	0.12	$	0.83	$	0.51	$	1.60

9. SEGMENT INFORMATION AND GEOGRAPHICAL DATA

Segment Information

We operate our business through two reportable business segments:


•	Sand - the production and sale of various grades of sand primarily used in the extraction of oil and natural gas and the production of numerous building products and foundry materials.


•	Fuel - the refining of transmix, distribution of finished fuel products, terminal and reclamation activities, and refining of biodiesel.

Segments have been identified based on how management makes operating decisions, assesses performance and allocates resources. Certain items are reviewed by our management on a consolidated basis, and are therefore presented as corporate income rather than segment income:


•	general and administrative costs related to corporate overhead, such as headquarters facilities and personnel, as well as equity-based compensation;


•	non-operating items such as interest, other income and income taxes.

Although not used by management in its performance monitoring activities, asset information is included in the following tables together with financial information concerning our reportable segments for the three and six months ended June 30, 2015 and 2014.

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	Three Months Ended June 30,
	Sand Segment				Fuel Segment				Corporate						Total
	2015		2014		2015		2014		2015			2014			2015		2014
	($ in thousands)
Revenues	$	68,118	$	77,470	$	132,734	$	220,803	$	—		$	—		$	200,852	$	298,273
Cost of goods sold (excluding depreciation, depletion and amortization)	50,738		51,860		126,195		209,535		—			—			176,933		261,395
Depreciation, depletion and amortization	4,713		2,688		2,634		3,017		8			6			7,355		5,711
Selling, general and administrative expenses	3,686		2,448		1,203		1,507		3,290			5,039			8,179		8,994
Project termination	2,693		—		—		—		—			—			2,693		—
Operating income (loss)	$	6,288	$	20,474	$	2,702	$	6,744	$	(3,298	)	$	(5,045	)	$	5,692	$	22,173



	Six Months Ended June 30,
	Sand Segment				Fuel Segment				Corporate						Total
	2015		2014		2015		2014		2015			2014			2015		2014
	($ in thousands)
Revenues	$	164,362	$	141,804	$	240,451	$	430,550	$	—		$	—		$	404,813	$	572,354
Cost of goods sold (excluding depreciation, depletion and amortization)	116,993		90,736		228,270		410,455		—			—			345,263		501,191
Depreciation, depletion and amortization	8,507		5,446		5,273		6,022		15			13			13,795		11,481
Selling, general and administrative expenses	7,403		5,664		2,803		2,789		7,576			9,016			17,782		17,469
Project termination	9,412		—		—		—		—			—			9,412		—
Operating income (loss)	$	22,047	$	39,958	$	4,105	$	11,284	$	(7,591	)	$	(9,029	)	$	18,561	$	42,213
Total assets (at period end)	$	269,205	$	202,349	$	146,754	$	169,183	$	3,303		$	17,821		$	419,262	$	389,353

Geographical Data

Although we own no long-term assets outside the United States, our Sand segment began selling product in Canada during 2013. We recognized $22.9 million and $21.0 million of revenues in Canada for the six months ended June 30, 2015 and 2014, respectively. All other sales have occurred in the United States.

10. DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES

We follow FASB ASC 820, Fair Value Measurement, which defines fair value, establishes a framework for measuring fair value, and specifies disclosures about fair value measurements. This guidance establishes a hierarchy for disclosure of the inputs to valuations used to measure fair value. The hierarchy prioritizes the inputs into three broad levels as follows.


•	Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities.


•	Level 2 inputs are quoted prices for similar assets and liabilities in active markets or inputs that are observable for the asset or liability, either directly or indirectly through market corroboration, for substantially the full term of the financial instrument.


•	Level 3 inputs are measured based on prices or valuation models that require inputs that are both significant to the fair value measurement and less observable from objective sources.

Our valuation models consider various inputs including (a) mark to market valuations, (b) time value and, (c) credit worthiness of valuation of the underlying measurement.

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A financial asset or liability’s classification within the hierarchy is determined based on the lowest level of input that is significant to the fair value measurement.

The following table shows the three interest rate swap agreements we entered into during 2013 to manage interest rate risk associated with our variable rate borrowings.



Agreement Date	Effective Date	Maturity Date	Notional Amount	Fixed Rate	Variable Rate
Nov. 1, 2013	Oct. 14, 2014	Oct. 16, 2017	$25,000,000	1.33200%	1 Month LIBOR
Nov. 7, 2013	Oct. 14, 2014	Oct. 16, 2017	$25,000,000	1.25500%	1 Month LIBOR
Nov. 21, 2013	Oct. 14, 2014	Oct. 16, 2017	$20,000,000	1.21875%	1 Month LIBOR

Our Fuel segment utilizes financial hedging arrangements whereby we hedge a portion of our gasoline and diesel inventory, which reduces our commodity price exposure on some of our activities. The derivative commodity instruments we utilize consist mainly of futures traded on the New York Mercantile Exchange. As of June 30, 2015 and December 31, 2014, we had 90 and 0 open commodity derivative contracts, respectively, to manage fuel price risk.

We do not designate our derivative instruments as hedges under GAAP. As a result, we recognize derivatives at fair value on the consolidated balance sheet with resulting gains and losses reflected in interest expense (for interest rate swap agreements) and cost of goods sold (for derivative commodity instruments), as reported in the condensed consolidated statements of operations. Our derivative instruments serve the same risk management purpose whether designated as a hedge or not. We derive fair values principally from published market interest rates and fuel price quotes (Level 2 inputs). The precise level of open position commodity derivatives is dependent on inventory levels, expected inventory purchase patterns and market price trends. We do not use derivative financial instruments for trading or speculative purposes.

The fair values of outstanding derivative instruments and their classifications within our Condensed Consolidated Balance Sheets are summarized as follows:



	June 30, 2015		December 31, 2014		Classification
	($ in thousands)
Derivative liabilities:
Interest rate swaps	$	714	$	422	Accrued liabilities
Commodity derivative contracts	$	97	$	—	Accrued liabilities

The effect of derivative instruments, none of which has been designated for hedge accounting, on our Condensed Consolidated Statements of Operations was as follows:



	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014		Classification
	(expense $ in thousands)
Interest rate swaps	$	101	$	498	$	681	$	633	Interest expense, net
Commodity derivative contracts	583		322		1,154		403		Cost of goods sold
	$	684	$	820	$	1,835	$	1,036

11. SUPPLEMENTAL CASH FLOW DISCLOSURES

The following supplemental disclosures may assist in the understanding of our Condensed Consolidated Statements of Cash Flows:



	Six Months Ended June 30,
	2015		2014
	($ in thousands)
Cash paid for interest	$	4,774	$	2,357
Cash paid for income taxes, net of refunds	$	484	$	163
Deferred compensation expense	$	—	$	81
Distribution equivalent rights accrued, net of payments	$	477	$	316
Capitalized reclamation costs	$	113	$	140
Purchases of PP&E accrued but not paid at period-end	$	1,847	$	4,102
Purchases of PP&E accrued in a prior period and paid in the current period	$	5,238	$	1,641

12. SUBSEQUENT EVENT

On July 23, 2015, the Board of Directors approved a quarterly distribution of $0.67 per common unit. We will pay $16.2 million on August 13, 2015 to holders of record as of August 5, 2015.

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Overview

We are a publicly-traded limited partnership formed in 2012 by management and affiliates of Insight Equity Management Company LLC and its affiliates (collectively “Insight Equity”) to own, operate, acquire and develop a diversified portfolio of energy service assets.

Our current operations are organized into two service-oriented business segments: our Sand segment and our Fuel segment (formerly referred to as our “Fuel Processing and Distribution” segment). Through our Sand segment, we are engaged in the businesses of mining, processing, and distributing silica sand, a key input for the hydraulic fracturing of oil and gas wells. Our Fuel segment processes transmix, distributes refined motor fuels and renewable fuels, operates bulk motor fuel storage terminals, and provides complementary services. We believe this diverse set of operations provides a stable cash flow profile when compared to companies with only one line of business.

We conduct our Sand operations through our subsidiary SSS and our Fuel operations through our subsidiaries Direct Fuels and AEC. We believe that our subsidiary brands, especially our SSS brand, have significant name recognition and a strong reputation with our customers.

The following discussion analyzes our financial condition and results of operations and should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2014, as well as historical condensed consolidated financial statements and notes included elsewhere in this Quarterly Report.

Acquisition of Mineral Reserves

On July 25, 2014, we completed an acquisition of mineral reserves and related assets to help manage the supply and cost of raw sand to our Wisconsin sand processing plants. See Note 1 to our Condensed Consolidated Financial Statements for further information.

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Results of Operations

The following table summarizes our consolidated operating results.



	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014
	($ in thousands)
Revenues	$	200,852		$	298,273		$	404,813		$	572,354

Operating expenses:
Cost of goods sold (excluding depreciation, depletion and amortization)	176,933			261,395			345,263			501,191
Depreciation, depletion and amortization	7,355			5,711			13,795			11,481
Selling, general and administrative expenses	8,179			8,994			17,782			17,469
Project termination	2,693			—			9,412			—
Total operating expenses	195,160			276,100			386,252			530,141
Operating income	5,692			22,173			18,561			42,213
Other expense (income):
Interest expense	2,632			1,943			5,761			3,527
Other	(15		)	(32		)	(44		)	(151		)
Total other expense	2,617			1,911			5,717			3,376
Income before provision for income taxes	3,075			20,262			12,844			38,837
Provision for income taxes	191			170			469			259
Net income	$	2,884		$	20,092		$	12,375		$	38,578

Adjusted EBITDA (a)	$	16,953		$	30,137		$	45,338		$	58,116

(a) See “Adjusted EBITDA” below for a discussion of Adjusted EBITDA and a reconciliation to net income (loss).

Recent Trends

Major factors impacting comparability between prior and future periods are:


•	a steep decline in the market prices for crude oil and refined products beginning in late 2014, impacting our Sand segment and Fuel segment;


•	a continuing reduction in oil and gas drilling activities in North America, resulting in lower sales volumes and sales prices for our frac sand in the near future;


•	development of our sand distribution and logistics services to better serve our customers through additional transload sites in 2013 and 2014 (currently shipping to 16 transload sites);


•	increasing fixed costs, such as railcar and transload facility costs, can increase our per-ton cost in times of declining sales volumes in our Sand segment;


•	the acquisition of mineral reserves and related assets in July 2014 to better manage the cost of raw sand for a portion of our Wisconsin plants’ production;


•	addition of the LP mine and wet plant, Thompson Hills mine and wet plant, and Arland dry plant in 2014; and


•	the Sand segment’s write-off of an incomplete construction project in Independence, Wisconsin, as discussed below.

Project termination

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Diesel Fuel

As discussed in our Annual Report on Form 10-K for the year ended December 31, 2014, railroads must begin purchasing Tier 4 locomotives, which only accept 15 ppm sulfur diesel, starting in 2015. As a result, the 500 ppm sulfur diesel our Fuel segment currently sells from our transmix processing has begun to be phased out of the locomotive market, beginning in the middle of 2015. During the quarter ended June 30, 2015, we adopted business practices to accommodate the shift in product mix from our railroad customers. The shift to other uses has proven less profitable and we expect this condition to continue until a more permanent solution is applied. To remediate this condition long term, we have contracted to purchase and install two hydrotreaters designed to remove incremental sulfur to the level of 15 ppm. At 15 ppm sulfur, diesel we derive from refined transmix can be sold for any legal use including railroads and road use transportation. We will install one unit at our Dallas-Ft. Worth, Texas facility and a second unit at our Birmingham, Alabama facility. We expect the hydrotreaters to become operational in the spring of 2016. We plan to invest approximately $17 million for both units, of which we had already paid $1.7 million as of June 30, 2015.

Sand Segment



	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
	($ in thousands)
Revenues	$	68,118	$	77,470	$	164,362	$	141,804
Operating expenses:
Cost of goods sold (excluding depreciation, depletion and amortization)	50,738		51,860		116,993		90,736
Depreciation, depletion and amortization	4,713		2,688		8,507		5,446
Selling, general and administrative expenses	3,686		2,448		7,403		5,664
Project termination	2,693		—		9,412		—
Operating income	$	6,288	$	20,474	$	22,047	$	39,958
Adjusted EBITDA (a)	$	13,935	$	23,184	$	40,226	$	45,421

Volume of sand sold (tons in thousands)	861		1,045		2,012		1,927
Volume of sand produced by dry plant (tons in thousands):
Arland, Wisconsin facility	248		—		653		—
Barron, Wisconsin facility	353		576		850		1,056
New Auburn, Wisconsin facility	178		330		483		650
Kosse, Texas facility	59		91		129		130
Total volume of sand produced	838		997		2,115		1,836

(a) See “Adjusted EBITDA” below for a discussion of Adjusted EBITDA and a reconciliation to net income (loss).

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

Revenues

Sand revenues decreased by $9.4 million, primarily due to significant price decreases and a 18% decrease in total volumes sold as a result of the downturn in market demand for frac sand. However, we have increased the volumes sold through transload sites from 14% to 39% of total volumes sold. We charge higher prices for sales from transload sites in order to cover the additional transportation costs.

The major changes from 2014 to 2015 are as follows:


•	$17.6 million decrease in sales of Northern White sand (excluding estimated transportation markups and shortfall revenues), relating primarily to a 17% decrease in volumes sold as well as decreased pricing in light of current market conditions for frac sand; and

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•	$0.4 million decrease in sales of native Texas sand (from our Kosse plant) due to a 30% decrease in volumes sold; offset by


•	$4.0 million of shortfall revenues recognized on a take-or-pay customer contract in 2015;


•	an estimated $2.8 million increase for higher markups due to increased volumes sold through transload sites, net of significant reductions in these markups per ton; and


•	$1.8 million of business interruption insurance proceeds to reimburse us for lost sales during a time of equipment failure in 2014.

Cost of goods sold (excluding depreciation, depletion and amortization)

Our cost of goods sold consists primarily of direct costs such as processing plant wages, royalties, mining, purchased sand, and transportation to the plant or to transload facilities, as well as indirect costs such as plant repairs and maintenance. Our direct costs of producing sand decreased with our decreased sales, but our logistics costs for finished product have increased as we expand our sales through transload sites. The most significant components of the $1.1 million decrease are:


•	$10.1 million decrease in the total cost to acquire and produce wet and dry sand, due mainly to lower sales volumes and lower-cost sources for wet sand;


•	$6.5 million increase in rail transportation-related expense, due mainly to higher rail use charges and railcar lease expense as we expand our shipping operations to transload facilities; and


•	$2.4 million increase in costs of transload facilities.

Depreciation, depletion and amortization

Depreciation, depletion and amortization increased by $2.0 million due mainly to deprecation of the Arland dry plant that was placed in service in December 2014 as well as depletion on the mineral reserves purchased in July 2014.

Selling, general and administrative expenses

The $1.2 million increase in selling, general and administrative expenses is attributable primarily to:


•	$0.6 million increase in employee-related costs;


•	$0.2 million bad debt expense; and


•	$0.2 million additional property taxes for sand processing assets.

Project termination

We recorded a $2.7 million charge to earnings for contract terminations and other non-recoverable costs incurred for an uncompleted construction project in Independence, Wisconsin. See Note 2 to our Condensed Consolidated Financial Statements for further discussion.

Six Months Ended June 30, 2015 Compared to Six Months Ended June 30, 2014

Revenues

Sand revenues increased by $22.6 million, primarily due to a 4% increase in total volumes sold, due to strong sales volumes in the first quarter of 2015, offset by significant price reductions. We have also increased the volumes sold through transload sites from 16% to 35% of total volumes sold. We charge higher prices for sales from transload sites in order to cover the additional transportation costs.

The major changes from 2014 to 2015 are as follows:


•	an estimated $22.7 million increase for higher markups related to transportation for increased sales through transload sites, net of reductions in these markups per ton;


•	$4.0 million of shortfall revenues recognized on a take-or-pay customer contract in 2015;


•	$1.4 million increase in sales of native Texas sand (from our Kosse plant) due to a 6% increase in volumes sold; and


•	$1.8 million of business interruption insurance proceeds to reimburse us for lost sales during a time of equipment failure in 2014; offset by


•	$7.4 million decrease in sales of Northern White sand (excluding estimated transportation markups and shortfall revenues), due to decrease pricing in light of current market conditions for frac sand, net of a slight increase in overall sales volumes.

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Cost of goods sold (excluding depreciation, depletion and amortization)


•	$25.6 million increase in rail transportation-related expense, due mainly to higher rail use charges and railcar lease expense as we expand our shipping operations to transload facilities; and


•	$3.8 million increase in costs of transload facilities; offset by


•	$3.1 million decrease in the cost of sand due mainly to lower cost sources of wet sand.

Depreciation, depletion and amortization

Depreciation, depletion and amortization increased by $3.1 million due mainly to deprecation of the Arland dry plant that was placed in service in December 2014 as well as depletion on the mineral reserves purchased in July 2014.

Selling, general and administrative expenses

The $1.7 million increase in selling, general and administrative expenses is attributable primarily to:


•	$0.7 million increase in employee-related costs;


•	$0.4 million additional property taxes for sand processing assets; and


•	$0.2 million bad debt expense.

Project termination

We recorded a $9.4 million charge to earnings for non-recoverable costs incurred for an uncompleted construction project. See Note 2 to our Condensed Consolidated Financial Statements for further discussion.

Fuel Segment



	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014
	($ in thousands)
Revenues	$	132,734		$	220,803		$	240,451		$	430,550
Operating expenses:
Cost of goods sold (excluding depreciation, depletion and amortization)	126,195			209,535			228,270			410,455
Depreciation, depletion and amortization	2,634			3,017			5,273			6,022
Selling, general and administrative expenses	1,203			1,507			2,803			2,789
Operating income	$	2,702		$	6,744		$	4,105		$	11,284
Adjusted EBITDA (a)	$	5,373		$	9,799		$	9,461		$	17,381

Volume of refined fuels sold (gallons in thousands)	63,402			70,514			119,797			138,742
Volume of terminal throughput (gallons in thousands)	40,796			57,877			80,027			114,751
Volume of transmix refined (gallons in thousands)	25,245			28,479			46,599			63,695
Refined transmix as a percent of total refined fuels sold	39.8		%	40.4		%	38.9		%	45.9		%

(a) See “Adjusted EBITDA” below for a discussion of Adjusted EBITDA and a reconciliation to net income (loss).

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

Revenues

The major components of the $88.1 million decrease in Fuel segment revenues are:


•	$66.1 million decrease due to lower average fuel sales prices;


•	$20.8 million decrease for lower volumes of fuel sold; and


•	$0.8 million decrease in excise and other transaction taxes.

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Cost of goods sold (excluding depreciation, depletion and amortization)

Our cost of goods sold consists primarily of direct costs associated with the purchase of refined fuels, transmix feedstock, plant labor and burden, and costs to operate our transmix and terminal facilities. The primary components of the $83.3 million decrease in costs of goods sold are:


•	$63.2 million decrease for lower average fuel purchase prices;


•	$19.4 million decrease for lower volumes of fuel sold; and


•	$0.8 million decrease in excise and other transaction taxes.

Depreciation, depletion and amortization

Depreciation, depletion and amortization decreased $0.4 million due primarily to full amortization of certain short-term intangible assets acquired in May 2013.

Six Months Ended June 30, 2015 Compared to Six Months Ended June 30, 2014

Revenues

The major components of the $190.1 million decrease in Fuel segment revenues are:


•	$133.9 million decrease due to lower average fuel sales prices;


•	$54.9 million decrease for lower volumes of fuel sold; and


•	$0.9 million decrease in excise and other transaction taxes.

Cost of goods sold (excluding depreciation, depletion and amortization)


•	$129.3 million decrease for lower average fuel purchase prices;


•	$51.6 million decrease for lower volumes of fuel sold; and


•	$0.9 million decrease in excise and other transaction taxes.

Depreciation, depletion and amortization

Depreciation, depletion and amortization decreased $0.7 million due primarily to full amortization of certain short-term intangible assets acquired in May 2013.

Corporate



	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014
	($ in thousands)
Depreciation, depletion and amortization	$	8		$	6		$	15		$	13
Selling, general and administrative expenses	3,290			5,039			7,576			9,016
Operating income (loss)	(3,298		)	(5,045		)	(7,591		)	(9,029		)
Other expense (income):
Interest expense, net	2,632			1,943			5,761			3,527
Other	(15		)	(32		)	(44		)	(151		)
Income (loss) before provision for taxes	(5,915		)	(6,956		)	(13,308		)	(12,405		)
Provision for income taxes	191			170			469			259
Unallocated corporate income (loss)	$	(6,106	)	$	(7,126	)	$	(13,777	)	$	(12,664	)
Adjusted EBITDA (a)	$	(2,355	)	$	(2,846	)	$	(4,349	)	$	(4,686	)

(a) See “Adjusted EBITDA” below for a discussion of Adjusted EBITDA and a reconciliation to net income (loss).

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

Selling, general and administrative expenses

The largest component of the $1.7 million decrease in selling, general and administrative expenses is the $1.3 million decrease in equity-based compensation expense resulting from the vesting of phantom units in May 2015.

Interest

Our interest expense increased by $0.7 million due to higher average balances on outstanding debt, slightly offset by smaller net losses on our interest rate swap agreements.

Six Months Ended June 30, 2015 Compared to Six Months Ended June 30, 2014

Selling, general and administrative expenses

The largest component of the by $1.4 million decrease in selling, general and administrative expenses is the $1.1 million decrease in equity-based compensation expense resulting from the vesting of phantom units in May 2015.

Interest

Our interest expense increased by $2.2 million due to higher average balances on outstanding debt as well as a slight increase in interest recognized for capital leases and long-term purchase obligations.

Liquidity and Capital Resources

Our principal liquidity requirements are to finance current operations, fund capital expenditures, including acquisitions from time to time, to service our debt and to pay distributions to partners. Our sources of liquidity generally include cash generated by our operations, borrowings under our revolving credit and security agreement and issuances of equity and debt securities. We believe that our leverage ratio (as defined in our Credit Agreement) will increase over the next 12 months, but that cash generated from our liquidity sources will be sufficient to meet our short-term working capital requirements and long-term capital expenditure requirements for at least the next twelve months.

Cash Flow Summary

The table below summarizes our cash flows.



	Six Months Ended June 30,
	2015			2014
	($ in thousands)
Cash flows from operating activities	$	39,913		$	29,578
Cash flows from investing activities	$	(15,543	)	$	(41,605	)
Cash flows from financing activities	$	(28,005	)	$	21,462
Cash and cash equivalents at beginning of period	$	6,876		$	2,167
Cash and cash equivalents at end of period	$	3,241		$	11,602

Operating cash flows

Net cash provided from operating activities has generally trended the same as our net income adjusted for non-cash items of depreciation, depletion and amortization, equity-based compensation, amortization of deferred financing costs, write-off of assets, and unrealized losses on derivative instruments. The changes in our operating assets and liabilities were also significantly impacted by lower accounts receivable balances resulting from lower sales of sand and fuel in 2015, a build-up of inventories in 2015, and higher spending for prepaid railcar lease assets in the second quarter of 2014.

Investing cash flows

As a result of the current market conditions, we have significantly curtailed our capital expenditure plans for 2015 and now expect to spend approximately $30 to $40 million dollars for capital expenditures for the full year 2015.

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Financing cash flows

The main categories of our financing cash flows can be summarized as follows:



	Six Months Ended June 30,
	2015			2014
	($ in thousands)
Net debt proceeds (payments)	$	31,947		$	75,986
Distributions to owners	(58,164		)	(51,481		)
Other	(1,788		)	(3,043		)
Total	$	(28,005	)	$	21,462

Contractual Obligations

The following table presents the remaining minimum contractual obligations as of June 30, 2015.



	Payments Due By Period
	Total		< 1 Year		1 - 3 Years		3 - 5 Years		> 5 Years
	($ in thousands)
Long-term debt (1)	$	287,303	$	4,337	$	17,267	$	265,699	$	—
Railcar leases (2)	490,376		28,645		112,554		120,720		228,457
Other operating leases (3)	7,307		1,343		2,284		838		2,842
Purchase commitments (4)	232,646		19,173		66,232		58,031		89,210
Minimum royalty payments (5)	8,370		240		960		960		6,210
Capital lease obligations	157		157		—		—		—
Total	$	1,026,159	$	53,895	$	199,297	$	446,248	$	326,719


(1)	Assumes balances outstanding as of 6/30/15 will be paid at maturity and includes interest using interest rates in effect at 6/30/15.


(2)	Includes minimum amounts payable under various operating leases for railcars as well as estimated costs to transport leased railcars from the manufacturer to our site for initial placement in service.


(3)	Includes lease agreements for land, facilities and equipment.


(4)	Includes minimum amounts payable under a business acquisition agreement, long-term rail transportation agreements, and other purchase commitments.


(5)	Represents minimum royalty payments for various sand mining locations. The amounts paid will differ based on amounts extracted.

ADJUSTED EBITDA

Adjusted EBITDA is a non-GAAP financial measure we define generally as: net income plus interest expense, tax expense, depreciation, depletion and amortization expense, non-cash charges and unusual or non-recurring charges less interest income, tax benefits and selected gains that are unusual or non-recurring. Adjusted EBITDA is used as a supplemental financial measure by our management and external users of our financial statements, such as investors and commercial banks, to assess:


•	the financial performance of our assets without regard to the impact of financing methods, capital structure or historical cost basis of our assets;


•	the viability of capital expenditure projects and the overall rates of return on alternative investment opportunities;


•	our liquidity position and the ability of our assets to generate cash sufficient to make debt payments and to make distributions; and


•	our operating performance as compared to those of other companies in our industry without regard to the impact of financing methods and capital structure.

We believe that Adjusted EBITDA provides useful information to investors because, when viewed with our GAAP results and the accompanying reconciliations, it provides a more complete understanding of our performance than GAAP results alone. We also believe that external users of our financial statements benefit from having access to the same financial measures that management

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uses in evaluating the results of our business. In addition, the lenders under our credit facility use a metric similar to Adjusted EBITDA to measure our compliance with certain financial covenants.

Adjusted EBITDA should not be considered an alternative to, or more meaningful than, net income, operating income, cash flows from operating activities or any other measure of financial performance presented in accordance with GAAP. Moreover, our Adjusted EBITDA as presented may not be comparable to similarly titled measures of other companies.

Reconciliation of Net Income (Loss) to Adjusted EBITDA

The following tables present a reconciliation of net income (loss) to Adjusted EBITDA for each segment, corporate, and in total.



	Three Months Ended June 30,
	Sand Segment					Fuel Segment				Corporate						Total
	2015		2014			2015		2014		2015			2014			2015			2014
	($ in thousands)
Net income (loss)	$	6,288	$	20,474		$	2,702	$	6,744	$	(6,106	)	$	(7,126	)	$	2,884		$	20,092
Interest expense, net	—		—			—		—		2,632			1,943			2,632			1,943
Other (income) loss	—		—			—		—		(15		)	(32		)	(15		)	(32		)
Provision for income taxes	—		—			—		—		191			170			191			170
Operating income (loss)	6,288		20,474			2,702		6,744		(3,298		)	(5,045		)	5,692			22,173
Depreciation, depletion and amortization	4,713		2,688			2,634		3,017		8			6			7,355			5,711
Equity-based compensation expense	—		—			—		—		935			2,193			935			2,193
Loss (gain) on disposal of equipment	—		19			—		—		—			—			—			19
Provision for doubtful accounts	221		(7		)	37		38		—			—			258			31
Accretion of asset retirement obligation	20		10			—		—		—			—			20			10
Project termination	2,693		—			—		—		—			—			2,693			—
Adjusted EBITDA	$	13,935	$	23,184		$	5,373	$	9,799	$	(2,355	)	$	(2,846	)	$	16,953		$	30,137



	Six Months Ended June 30,
	Sand Segment					Fuel Segment				Corporate						Total
	2015		2014			2015		2014		2015			2014			2015			2014
	($ in thousands)
Net income (loss)	$	22,047	$	39,958		$	4,105	$	11,284	$	(13,777	)	$	(12,664	)	$	12,375		$	38,578
Interest expense, net	—		—			—		—		5,761			3,527			5,761			3,527
Other (income) loss	—		—			—		—		(44		)	(151		)	(44		)	(151		)
Provision for income taxes	—		—			—		—		469			259			469			259
Operating income (loss)	22,047		39,958			4,105		11,284		(7,591		)	(9,029		)	18,561			42,213
Depreciation, depletion and amortization	8,507		5,446			5,273		6,022		15			13			13,795			11,481
Equity-based compensation expense	—		—			—		—		3,227			4,330			3,227			4,330
Loss (gain) on disposal of equipment	—		19			8		—		—			—			8			19
Provision for doubtful accounts	221		(12		)	75		75		—			—			296			63
Accretion of asset retirement obligation	39		10			—		—		—			—			39			10
Project termination	9,412		—					—								9,412			—
Adjusted EBITDA	$	40,226	$	45,421		$	9,461	$	17,381	$	(4,349	)	$	(4,686	)	$	45,338		$	58,116

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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Information about market risks for the six months ended June 30, 2015, does not differ materially from that discussed under Item 7A of our Annual Report on Form 10-K for 2014.

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of disclosure controls and procedures

We maintain disclosure controls and procedures (as defined in Rule 13a-15(e) of the Securities Exchange Act of 1934, as amended (the “Exchange Act”)) designed to provide reasonable assurance that the information required to be disclosed in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s (“SEC”) rules and forms, including controls and procedures designed to ensure that this information is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure. It should be noted that, because of inherent limitations, our disclosure controls and procedures, however well designed and operated, can provide only reasonable, and not absolute, assurance that the objectives of the disclosure controls and procedures are met.

In connection with the preparation of this Quarterly Report, our management, with the participation of our Chief Executive Officer and our Chief Financial Officer, carried out an evaluation of the effectiveness of the design and operation of our disclosure controls and procedures (as required by Rule 13a-15(b) of the Exchange Act), as of June 30, 2015. In making this evaluation, our management considered the matters relating to the material weaknesses disclosed in our Annual Report on Form 10-K for the year ended December 31, 2014. Based on this evaluation, and because we are continuing to remediate the material weakness regarding information technology and Sand segment activity controls as described below, our Chief Executive Officer and Chief Financial Officer concluded that the Company’s disclosure controls and procedures (as defined in Rule 13a-15(e) of the Exchange Act) were not effective as of June 30, 2015.

Remediation of previously reported material weaknesses

Information Technology Controls

We are in the process of remediating information technology general control deficiencies that contributed to our material weakness in information technology control activities. Management is currently evaluating the effectiveness of remediation efforts implemented during the second quarter of 2015; and in connection with those efforts, management has:


•	added, and continues to add, competent information technology support personnel as outlined in the headcount and competency gap analysis performed by management shortly after issuing the 2014 10-K;


•	provided training for new and existing information technology personnel to improve competencies and understanding of information technology policies, monitoring activities, and controls established by management and the board of directors of our general partner; and


•	removed, and continues to remove, system access rights that result in segregation of duty conflicts that are not mitigated with manual compensating controls or processes.

Sand Segment Control Activities

We are in the process of remediating Sand segment accounting control deficiencies that contributed to our material weakness in Sand segment control activities. Management is currently evaluating the effectiveness of remediation efforts implemented during the second quarter of 2015; and in connection with those efforts, management has:


•	added, and continues to add, competent accounting and finance personnel as outlined in the headcount and competency gap analysis performed by management shortly after issuing the 2014 10-K;


•	provided training for new and existing Sand segment accounting and finance personnel to improve competencies and understanding in regards to the Sand segment’s procurement, general and railcar lease accounting, and capital expenditures policies, controls, and documentation requirements established by management and the board of directors of our general partner;


•	implemented and continue to implement, additional controls related to the Sand segment’s procurement, general and railcar lease accounting, and capital expenditures processes; and


•	implemented compensating manual controls and processes related to the remaining system access conflicts for Sand segment accounting and finance personnel.

Other Remediation Activities

In addition to the above actions, management has engaged outside resources with expertise in internal controls to assist in the remediation of both material weaknesses.

PART II OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

Although we are, from time to time, involved in litigation and claims arising out of our operations in the normal course of business, we do not believe that we are a party to any litigation that could have a material adverse impact on our financial condition or results of operations. We are not aware of any undisclosed significant legal or governmental proceedings against us, or contemplated to be brought against us. We maintain such insurance policies with insurers in amounts and with coverage and deductibles as our general partner believes are reasonable and prudent. However, we cannot assure you that this insurance will be adequate to protect us from all material expenses related to potential future claims for personal and property damage or that these levels of insurance will be available in the future at acceptable prices.

Environmental Matter

On November 21, 2013, the EPA issued a General Notice Letter and Information Request (“Notice”) under Section 104(e) of CERCLA to one of our subsidiaries operating within the Fuel segment. The Notice provides that the subsidiary may have incurred liability with respect to the Reef Environmental site in Alabama, and requested certain information in accordance with Section 107(a) of CERCLA. We timely responded to the Notice. At this time, no specific claim for cost recovery has been made by the EPA (or any other potentially responsible party) against us. There is uncertainty relating to our share of environmental remediation liability, if any, because our allocable share of wastewater is unknown and the total remediation cost is also unknown. Consequently, management is unable to estimate the possible loss or range of loss, if any. We have not recorded a loss contingency accrual in our financial statements. In the opinion of management, the outcome of such matters will not have a material adverse effect on our financial position, liquidity or results of operations.

ITEM 1A. RISK FACTORS

In addition to the other information set forth in this report, you should carefully consider the factors discussed in Part I, “Item 1A. Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2014, which could materially affect our business, financial condition or future results. The risks described in this report and in our Annual Report on Form 10-K are not the only risks we face. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial also may materially adversely affect our business, financial condition or future results.

ITEM 4. MINE SAFETY DISCLOSURES

We adhere to a strict occupational health program aimed at controlling exposure to silica dust, which includes dust sampling, a respiratory protection program, medical surveillance, training and other components. We designed our safety program to ensure compliance with the standards of our Occupational Health and Safety Manual and U.S. Federal Mine Safety and Health Administration (“MSHA”) regulations. For both health and safety issues, extensive training is provided to employees. We have organized safety committees at our plants made up of both salaried and hourly employees. We perform annual internal health and safety audits and conduct semi-annual crisis management drills to test our abilities to respond to various situations. Our corporate health and safety department administers the health and safety programs with the assistance of plant environmental, health and safety coordinators.

All of our production facilities are classified as mines and are subject to regulation by MSHA under the Federal Mine Safety and Health Act of 1977 (the “Mine Act”). MSHA inspects our mines on a regular basis and issues various citations and orders when it believes a violation has occurred under the Mine Act. Following passage of The Mine Improvement and New Emergency Response Act of 2006, MSHA significantly increased the numbers of citations and orders charged against mining operations. The dollar penalties assessed for citations issued has also increased in recent years. Information concerning mine safety violations or other regulatory matters required by Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K (17 CFR 229.104) is included in Exhibit 95.1 to this Quarterly Report on Form 10-Q.

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ITEM 6. EXHIBITS



Exhibit Number		Description

3.1		Certificate of Limited Partnership of Emerge Energy Services LP (incorporated by reference to Exhibit 3.1 to the Registrant’s Registration Statement on Form S-1, Registration No. 333-187487).

3.2		Amendment to Certificate of Limited Partnership of Emerge Energy Services LP (incorporated by reference to Exhibit 3.2 to the Registrant’s Registration Statement on Form S-1, Registration No. 333-187487).

3.3		First Amended and Restated Limited Partnership Agreement of Emerge Energy Services LP, dated as of May 14, 2013 (incorporated by reference to Exhibit 3.1 to the Registrant’s Current Report on Form 8-K, filed with the SEC on May 20, 2013).

3.4		Certificate of Limited Formation of Emerge Energy Services GP LLC (incorporated by reference to Exhibit 3.5 to the Registrant’s Registration Statement on Form S-1, Registration No. 333-187487).

3.5		Amendment to Certificate of Formation of Emerge Energy Services GP LLC (incorporated by reference to Exhibit 3.6 to the Registrant’s Registration Statement on Form S-1, Registration No. 333-187487).

3.6		Amended and Restated Limited Liability Company Agreement of Emerge Energy Services GP, LLC, dated as of May 14, 2013 (incorporated by reference to Exhibit 3.2 to the Registrant’s Current Report on Form 8-K, filed with the SEC on May 20, 2013).

10.1		First Amendment to Amended and Restated Revolving Credit and Security Agreement, dated as of April 6, 2015, among Emerge Energy Services LP, as parent guarantor, the Borrowers party thereto, PNC Bank, National Association, as administrative agent and collateral agent, and the Lenders party thereto (incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K, filed with the SEC on April 8, 2015 ).

10.2		Employment Letter, dated April 13, 2015 between Emerge Energy Services GP LLC and Jody Tusa (incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K, filed with the SEC on May 4, 2015).

31.1*		Certification of Chief Executive Officer under Section 302 of the Sarbanes-Oxley Act of 2002.

31.2*		Certification of Chief Financial Officer under Section 302 of the Sarbanes-Oxley Act of 2002.

32.1*		Certification of Chief Executive Officer under Section 906 of the Sarbanes-Oxley Act of 2002.

32.2*		Certification of Chief Financial Officer under Section 906 of the Sarbanes-Oxley Act of 2002.

95.1*		Mine Safety Disclosure Exhibit.

101*		Interactive Data Files - XBRL.

* Filed herewith (or furnished in the case of Exhibits 32.1 and 32.2).

Table of Contents

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

Date: August 6, 2015



	EMERGE ENERGY SERVICES LP

	By:	EMERGE ENERGY SERVICES GP LLC, its general partner

	By:	/s/ Rick Shearer
		Rick Shearer
		President and Chief Executive Officer
		(Principal Executive Officer)

	By:	/s/ Joseph C. Tusa, Jr.
		Joseph C. Tusa, Jr.
		Chief Financial Officer
		(Principal Financial Officer)

Table of Contents

INDEX TO EXHIBITS



Exhibit Number		Description

3.1		Certificate of Limited Partnership of Emerge Energy Services LP (incorporated by reference to Exhibit 3.1 to the Registrant’s Registration Statement on Form S-1, Registration No. 333-187487).

3.2		Amendment to Certificate of Limited Partnership of Emerge Energy Services LP (incorporated by reference to Exhibit 3.2 to the Registrant’s Registration Statement on Form S-1, Registration No. 333-187487).

3.3		First Amended and Restated Limited Partnership Agreement of Emerge Energy Services LP, dated as of May 14, 2013 (incorporated by reference to Exhibit 3.1 to the Registrant’s Current Report on Form 8-K, filed with the SEC on May 20, 2013).

3.4		Certificate of Limited Formation of Emerge Energy Services GP LLC (incorporated by reference to Exhibit 3.5 to the Registrant’s Registration Statement on Form S-1, Registration No. 333-187487).

3.5		Amendment to Certificate of Formation of Emerge Energy Services GP LLC (incorporated by reference to Exhibit 3.6 to the Registrant’s Registration Statement on Form S-1, Registration No. 333-187487).

3.6		Amended and Restated Limited Liability Company Agreement of Emerge Energy Services GP, LLC, dated as of May 14, 2013 (incorporated by reference to Exhibit 3.2 to the Registrant’s Current Report on Form 8-K, filed with the SEC on May 20, 2013).

10.1		First Amendment to Amended and Restated Revolving Credit and Security Agreement, dated as of April 6, 2015, among Emerge Energy Services LP, as parent guarantor, the Borrowers party thereto, PNC Bank, National Association, as administrative agent and collateral agent, and the Lenders party thereto (incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K, filed with the SEC on April 8, 2015 ).

10.2		Employment Letter, dated April 13, 2015 between Emerge Energy Services GP LLC and Jody Tusa (incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K, filed with the SEC on May 4, 2015).

31.1*		Certification of Chief Executive Officer under Section 302 of the Sarbanes-Oxley Act of 2002.

31.2*		Certification of Chief Financial Officer under Section 302 of the Sarbanes-Oxley Act of 2002.

32.1*		Certification of Chief Executive Officer under Section 906 of the Sarbanes-Oxley Act of 2002.

32.2*		Certification of Chief Financial Officer under Section 906 of the Sarbanes-Oxley Act of 2002.

95.1*		Mine Safety Disclosure Exhibit.

101*		Interactive Data Files - XBRL.

* Filed herewith (or furnished in the case of Exhibits 32.1 and 32.2).

Attached files

Emerge Energy Services LP Reports

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