Westmoreland Resource Partners, LP - FORM 10-Q - May 15, 2017

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EX-95.1 - EXHIBIT 95.1 - Westmoreland Resource Partners, LPq12017exhibit_951.htm
EX-32 - EXHIBIT 32 - Westmoreland Resource Partners, LPq12017exhibit_32.htm
EX-31.2 - EXHIBIT 31.2 - Westmoreland Resource Partners, LPq12017exhibit_312.htm
EX-31.1 - EXHIBIT 31.1 - Westmoreland Resource Partners, LPq12017exhibit_311.htm

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
 
FORM 10-Q 
(Mark One)
☒
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 
For the quarterly period ended March 31, 2017
OR
☐
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 
Commission file number: 001-34815
_________________________
Westmoreland Resource Partners, LP
(Exact name of registrant as specified in its charter)
____________________________________________________
Delaware
77-0695453
(State or other jurisdiction of incorporation or organization)
(I.R.S. Employer Identification No.)
9540 South Maroon Circle, Suite 300 Englewood, CO
80112
(Address of principal executive offices)
(Zip Code)
Registrant’s telephone number, including area code: (855) 922-6463
 _________________________________________
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.
Yes ☒ 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).
Yes ☒ No ☐
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and "emerging growth company" in Rule 12b-2 of the Exchange Act.
Large accelerated filer
o
 
Accelerated filer
o
Non-accelerated filer
x
(Do not check if a smaller reporting company.)
Smaller reporting company
o
 
 
 
Emerging growth company
o
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o

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

As of May 12, 2017, 1,284,840 common units representing limited partner interests in Westmoreland Resource Partners, LP (“Common Units”) were outstanding. The Common Units trade on the New York Stock Exchange under the ticker symbol “WMLP.” 


TABLE OF CONTENTS 

2


PART I - FINANCIAL INFORMATION
ITEM 1
FINANCIAL STATEMENTS

WESTMORELAND RESOURCE PARTNERS, LP AND SUBSIDIARIES
Consolidated Balance Sheets
(Unaudited)
 
March 31, 2017
 
December 31, 2016
 
(In thousands)
Assets
 
Current assets:
 
 
 
Cash
$
20,234

 
$
15,094

Receivables
30,427

 
37,587

Inventories
17,480

 
17,559

Assets held for sale
636

 
934

Other current assets
4,772

 
5,794

Total current assets
73,549

 
76,968

Property, plant and equipment:
 
 
 
Land, mineral rights, property, plant and equipment
362,325

 
359,748

Less accumulated depreciation, depletion and amortization
(134,483
)
 
(124,130
)
Net property, plant and equipment
227,842

 
235,618

Advanced coal royalties
8,979

 
8,815

Restricted investments
38,111

 
37,741

Intangible assets, net of accumulated amortization of $4.6 million and $4.1 million at March 31, 2017 and December 31, 2016, respectively
26,632

 
27,148

Deposits and other assets
468

 
617

Total Assets
$
375,581

 
$
386,907

Liabilities and Partners’ Capital
 
 
 
Current liabilities:
 
 
 
Current installments of long-term debt
$
4,179

 
$
3,819

Accounts payable and accrued expenses:
 
 
 
Trade
14,355

 
19,397

Deferred revenue
5,993

 
3,547

Production taxes
18,279

 
16,319

Asset retirement obligations
10,395

 
10,775

Other current liabilities
2,402

 
3,284

Total current liabilities
55,603

 
57,141

Long-term debt, less current installments
315,374

 
313,827

Asset retirement obligations, less current portion
40,506

 
41,402

Other liabilities
2,551

 
2,647

Total liabilities
414,034

 
415,017

Partners’ capital (deficit):
 
 
 
Limited partners (1,284,840 and 1,221,060 units outstanding as of March 31, 2017 and December 31, 2016, respectively)
27,614

 
28,261

Series A Convertible Units (16,215,029 and 15,656,551 units outstanding as of March 31, 2017 and December 31, 2016, respectively)
(52,574
)
 
(46,103
)
Series B Convertible Units (4,512,500 units outstanding as of March 31, 2017 and December 31, 2016)
(45,187
)
 
(43,360
)
General partner (35,291 units outstanding as of March 31, 2017 and December 31, 2016)
31,737

 
33,281

Accumulated other comprehensive loss
(43
)
 
(189
)
Total Westmoreland Resource Partners, LP deficit
(38,453
)
 
(28,110
)
Total Liabilities and Partners’ Capital
$
375,581

 
$
386,907


See accompanying Notes to Consolidated Financial Statements (Unaudited). 

3


WESTMORELAND RESOURCE PARTNERS, LP AND SUBSIDIARIES
Consolidated Statements of Operations and Comprehensive Loss
(Unaudited)
 
Three Months Ended March 31,
 
2017
 
2016
 
(In thousands, except per unit data)
Revenues:
 
 
 
Coal revenues
$
73,107

 
$
91,560

Non-coal revenues
1,698

 
922

Total revenues
74,805

 
92,482

Costs and expenses:
 
 
 
Cost of coal revenues
59,325

 
71,211

Cost of non-coal revenues
91

 
153

Depreciation, depletion and amortization
10,351

 
15,265

Selling and administrative
3,897

 
3,268

(Gain) loss on sales of assets
(142
)
 
1,229

Loss on impairment
—

 
538

Total cost and expenses
73,522

 
91,664

Operating income
1,283

 
818

Other (expense) income:
 
 
 
Interest expense
(10,479
)
 
(9,848
)
Interest income
206

 
340

Other income
44

 
24

Change in fair value of warrants
131

 
(190
)
Total other expenses
(10,098
)
 
(9,674
)
Net loss
(8,815
)
 
(8,856
)
Less net loss allocated to general partner
(13
)
 
(14
)
Net loss allocated to limited partners
$
(8,802
)
 
$
(8,842
)
 
 
 
 
Net loss
$
(8,815
)
 
$
(8,856
)
Unrealized and realized gain (loss) on available-for-sale securities
146

 
(28
)
Comprehensive loss attributable to the Partnership
$
(8,669
)
 
$
(8,884
)
 
 
 
 
Net loss per common limited partner unit, basic and diluted:
$
(0.32
)
 
$
(0.41
)
 
 
 
 
Weighted average number of common limited partner units outstanding, basic and diluted:
1,451

 
5,885

 
 
 
 
Cash distribution paid per common limited partner unit
$
0.1333

 
$
0.2000

Cash distribution paid per general partner unit
0.1333

 
0.2000


See accompanying Notes to Consolidated Financial Statements (Unaudited). 

4

WESTMORELAND RESOURCE PARTNERS, LP AND SUBSIDIARIES
Consolidated Statements of Partners’ Capital (Deficit)
(Unaudited)
 
 
Limited Partners
 
 
 
 
 
 
 
Total Partners' Deficit
 
Common
 
Series A Convertible
 
Series B Convertible
 
Liquidation
 
Total
 
General Partner
 
Accumulated Other Comprehensive Loss
 
 
Units
 
Capital (Deficit)
 
Units
 
Deficit
 
Units
 
Deficit
 
Units
 
Capital
 
Units
 
Deficit
 
Units
 
Capital
 
 
 
(In thousands, except units data)
Balance at December 31, 2016
1,221,060

 
$
28,261

 
15,656,551

 
$
(46,103
)
 
4,512,500

 
$
(43,360
)
 
856,698

 
$
—

 
22,246,809

 
$
(61,202
)
 
35,291

 
$
33,281

 
$
(189
)
 
$
(28,110
)
Net loss
—

 
(504
)
 
—

 
(6,471
)
 
—

 
(1,827
)
 
—

 
—

 
—

 
(8,802
)
 
—

 
(13
)
 
—

 
(8,815
)
Equity-based compensation
—

 
42

 
—

 
—

 
—

 
—

 
—

 
—

 
—

 
42

 
—

 
—

 
—

 
42

Issuance of units to LTIP participants
63,780

 
—

 
—

 
—

 
—

 
—

 
—

 
—

 
63,780

 
—

 
—

 
—

 
—

 
—

Other comprehensive income
—

 
—

 
—

 
—

 
—

 
—

 
—

 
—

 
—

 
—

 
—

 
—

 
146

 
146

Distribution for acquisition of Johnson Run (Note 12)
—

 
—

 
—

 
—

 
—

 
—

 
—

 
—

 
—

 
—

 
—

 
(1,526
)
 
—

 
(1,526
)
Paid-in-kind Series A convertible unit distribution
—

 
—

 
558,478

 
—

 
—

 
—

 
—

 
—

 
558,478

 
—

 
—

 
—

 
—

 
—

Cash distribution to unitholders
—

 
(185
)
 
—

 
—

 
—

 
—

 
—

 
—

 
—

 
(185
)
 
—

 
(5
)
 
—

 
(190
)
Balance at March 31, 2017
1,284,840

 
$
27,614

 
16,215,029

 
$
(52,574
)
 
4,512,500

 
$
(45,187
)
 
856,698

 
$
—

 
22,869,067

 
$
(70,147
)
 
35,291

 
$
31,737

 
$
(43
)
 
$
(38,453
)
 
See accompanying Notes to Consolidated Financial Statements (Unaudited). 

5

WESTMORELAND RESOURCE PARTNERS, LP AND SUBSIDIARIES
Consolidated Statements of Cash Flows
(Unaudited)

 
Three Months Ended March 31,
 
2017
 
2016
 
(In thousands)
Cash flows from operating activities:
 
 
 
Net loss
$
(8,815
)
 
$
(8,856
)
Adjustments to reconcile net loss to net cash provided by operating activities:
 
 
 
Depreciation, depletion and amortization
10,351

 
15,265

Accretion of asset retirement obligations
1,335

 
1,375

Impairment charges
—

 
538

Non-cash interest expense
2,296

 
2,269

Amortization of deferred financing costs
706

 
527

Other
(1,019
)
 
1,483

Changes in operating assets and liabilities:
 
 
 
Receivables, net
7,160

 
(3,124
)
Inventories
79

 
2,361

Accounts payable and accrued expenses
(2,686
)
 
(3,043
)
Accrued interest expense
49

 
(62
)
Deferred revenue
2,446

 
3,572

Other assets and liabilities
1,195

 
74

Asset retirement obligations
(1,877
)
 
(1,452
)
Net cash provided by operating activities
11,220

 
10,927

Cash flows from investing activities:
 
 
 
Additions to property, plant, equipment and other
(3,221
)
 
(1,544
)
Advance royalties payments
(267
)
 
(8
)
Change in restricted investments
(224
)
 
(2,516
)
Net proceeds from sales of assets
407

 
214

Net cash used in investing activities
(3,305
)
 
(3,854
)
Cash flows from financing activities:
 
 
 
Repayments of long-term debt
(1,059
)
 
(941
)
Cash distributions to unitholders
(190
)
 
(1,183
)
Acquisition under common control of Johnson Run
(1,526
)
 
—

Net cash used in financing activities
(2,775
)
 
(2,124
)
Net increase in cash
5,140

 
4,949

Cash, beginning of the period
15,094

 
3,710

Cash, end of the period
$
20,234

 
$
8,659

Supplemental disclosures of cash flow information:
 
 
 
Cash paid for interest
$
7,428

 
$
7,052

Non-cash transactions:
 
 
 
Asset retirement obligations capitalized in mine development
$
—

 
$
794

Market value of common units vested in LTIP
327

 
86

Market value of Series A units at date of distribution
2,124

 
3,050

 
See accompanying Notes to Consolidated Financial Statements (Unaudited).

6

WESTMORELAND RESOURCE PARTNERS, LP AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

1. BASIS OF PRESENTATION
The accompanying unaudited consolidated financial statements include the accounts and operations of Westmoreland Resource Partners, LP (the "Partnership") and its consolidated subsidiaries and have been prepared in accordance with United States generally accepted accounting principles (“GAAP”) and require the use of management’s estimates. The financial information contained in this Quarterly Report on Form 10-Q is unaudited, but reflects all adjustments which in the opinion of management are necessary for a fair presentation of the financial information for the periods shown. Such adjustments are of a normal recurring nature. Certain prior-year amounts have been reclassified to conform with the financial statement line items used by Westmoreland Coal Company (“WCC”), the parent of our general partner Westmoreland Resources GP, LLC (the "GP"). The results of operations for the three months ended March 31, 2017 are not necessarily indicative of results to be expected for the year ending December 31, 2017.
These unaudited quarterly consolidated financial statements should be read in conjunction with the consolidated financial statements and notes included in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2016 (“2016 Form 10-K”). There were no changes to our significant accounting policies from those disclosed in the audited consolidated financial statements and notes thereto contained in our 2016 Form 10-K, except as described below.
Accounting Pronouncements Effective in the Future
In February 2016, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2016-02, "Leases (Topic 842)" which requires companies leasing assets to recognize on their balance sheet a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term on contracts longer than one year. The lessee is permitted to make an accounting policy election to not recognize lease assets and lease liabilities for short-term leases. How leases are recorded on the balance sheet represents a significant change from previous GAAP guidance as described in ASU "Leases (Topic 840)." ASU 2016-02 maintains a distinction between finance leases and operating leases similar to the distinction under previous lease guidance for capital leases and operating leases. The impact of leases reported in the Partnership’s operating results and statement of cash flows are expected to be similar to previous GAAP.
ASU 2016-02 is effective for fiscal years beginning after December 15, 2018, and early adoption is permitted. Adoption of the new lease accounting standard will require the Partnership to apply the new standard to the earliest period using a modified retrospective approach. The Partnership is currently in the process of evaluating the impact of the new standard, including the evaluation of the impact, if any, on changes to business processes, systems and controls to support recognition and disclosure under the new guidance, however, at this time is unable to determine the impact this standard will have on the financial statements and related disclosures.
In January 2016, the FASB issued ASU 2016-01, "Financial Instruments - Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities" which updates certain aspects of recognition, measurement, presentation and disclosure of financial instruments. This standard is effective for interim and annual periods beginning after December 15, 2017. We are currently evaluating the effect adopting this guidance will have on our consolidated financial statements and footnote disclosures.
In May 2014, the FASB issued ASU 2014-09, "Revenue from Contracts with Customers," issued as a new Topic, ASC Topic 606. The new revenue recognition standard supersedes all existing revenue recognition guidance. Under this ASU, an entity should recognize revenue when it transfers 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. ASU 2015-14, issued in August 2015, deferred the effective date of ASU 2014-09 to the first quarter of 2018, with early adoption permitted in the first quarter of 2017. The Partnership intends to adopt the amended guidance as of January 1, 2018.
In March, April, May, and December 2016, the FASB issued the following updates, respectively, to provide supplemental adoption guidance and clarification to ASU 2014-09. These standards must be adopted concurrently upon the adoption of ASU 2014-09. We are currently evaluating the potential effects of adopting the provisions of these updates.
•
ASU 2016-08, Revenue from Contracts with Customers: Principal versus Agent Considerations (Reporting Revenue Gross versus Net).
•
ASU 2016-10, Revenue from Contracts with Customers: Identifying Performance Obligations and Licensing.
•
ASU 2016-12, Revenue from Contracts with Customers: Narrow-Scope Improvements and Practical Expedients.

7
WESTMORELAND RESOURCE PARTNERS, LP AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

•
ASU 2016-19, Technical Corrections and Improvements.

During 2016, the Partnership established an implementation team to develop a multi-phase plan to adopt the requirements of the new standard. The team is in the process of developing its conclusions on several aspects of the standard including principal versus agent considerations, identification of performance obligations and the determination of when control of goods and services transfers to the Partnership’s customers. Under the new standard, companies may use either of the following transition methods: (i) a full retrospective approach reflecting the application of the standard in each prior reporting period with the option to elect certain practical expedients, or (ii) a modified retrospective approach with the cumulative effect of initially adopting ASU 2014-09 recognized at the date of adoption (which includes additional footnote disclosures). We have not concluded which transition method we will elect, but we currently anticipate using the full retrospective approach.
2. INVENTORIES
Inventories consisted of the following:
 
March 31, 2017
 
December 31, 2016
 
(In thousands)
Coal stockpiles
$
5,514

 
$
4,518

Materials and supplies
12,016

 
13,091

Reserve for obsolete inventory
(50
)
 
(50
)
Total
$
17,480

 
$
17,559

3. RESTRICTED INVESTMENTS
The Partnership invests certain bond collateral in a limited selection of fixed-income investment options and receives the investment returns on these investments. These investments are not available to meet the Partnership’s general cash needs. These investments include available-for-sale securities. Available-for-sale securities are reported at fair value with unrealized gains and losses excluded from earnings and reported in Accumulated other comprehensive loss.
The carrying value and estimated fair value of our restricted investments were as follows:
 
March 31, 2017
 
December 31, 2016
 
(In thousands)
Cash and cash equivalents
$
7,011

 
$
8,581

Available-for-sale securities
31,100

 
29,160

 
$
38,111

 
$
37,741


Available-for-Sale Restricted Investments

The cost basis, gross unrealized holding gains and losses and fair value of available-for-sale securities were as follows:
 
March 31, 2017
 
December 31, 2016
 
(In thousands)
Cost basis
$
31,143

 
$
29,349

Gross unrealized holding gains
221

 
167

Gross unrealized holding losses for less than one year
(109
)
 
(106
)
Gross unrealized holding losses for more than one year
(155
)
 
(250
)
Fair Value
$
31,100

 
$
29,160


4. IMPAIRMENT CHARGES
In the first quarter of 2016, management made an operating decision to part-out and scrap a large-capacity shovel resulting in an impairment charge of $0.5 million for the three months ended March 31, 2016. There were no impairment charges incurred for the three months ended March 31, 2017.

8
WESTMORELAND RESOURCE PARTNERS, LP AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

5. DEBT AND LINES OF CREDIT
Debt consisted of the following:
 
March 31, 2017
 
December 31, 2016
 
(In thousands)
Term loan facility
$
308,116

 
$
306,189

Capital lease obligations
15,713

 
16,351

Other
536

 
589

Total debt outstanding
324,365

 
323,129

Less debt issuance costs
(4,812
)
 
(5,483
)
Less current installments
(4,179
)
 
(3,819
)
Total debt outstanding, less current installments
$
315,374

 
$
313,827


The following table presents remaining aggregate contractual debt maturities of all long-term debt: 
 
March 31, 2017
 
(In thousands)
2017
$
3,072

2018
312,292

2019
4,105

2020
1,694

2021
1,586

Thereafter
1,616

Total debt
$
324,365


Credit Facilities
2014 Financing Agreement
On December 31, 2014, we entered into a financing agreement with the lenders party thereto and U.S. Bank National Association, as administrative and collateral agent (the “2014 Financing Agreement”). As of March 31, 2017, we had a term loan of $308.1 million outstanding under the 2014 Financing Agreement. Borrowings on such term loan bear interest at a variable rate per annum equal to, at our option, (1) the three-month London Interbank Offered Rate (“LIBOR”) (subject to a floor of 0.75%) plus 8.5% or (ii) the Reference Rate (as defined in the 2014 Financing Agreement). As of March 31, 2017, the 2014 Financing Agreement had a cash interest rate of 9.65%, consisting of the LIBOR (1.15%) plus 8.5%. The term loan under the 2014 Financing Agreement matures on December 31, 2018.
The 2014 Financing Agreement also provides for “PIK Interest” (as defined in the 2014 Financing Agreement) at a variable rate per annum between 1.00% and 3.00% based on our Consolidated Total Net Leverage Ratio (as defined in the 2014 Financing Agreement). The rate of PIK Interest is recalculated on a quarterly basis with the PIK Interest added quarterly to the then-outstanding principal amount of the term loan under the 2014 Financing Agreement. PIK Interest under the 2014 Financing Agreement was $2.3 million for the three months ended March 31, 2017. The outstanding term loan amount represents the principal balance of $289.7 million, plus PIK Interest of $18.4 million.
During the three months ended March 31, 2017, we paid down $0.4 million of the term loan under the 2014 Financing Agreement with proceeds from oil and gas royalties received. The 2014 Financing Agreement requires mandatory prepayment of principal with proceeds from such events.

9
WESTMORELAND RESOURCE PARTNERS, LP AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

In connection with the acquisition of the Kemmerer Mine, in Lincoln county Wyoming, from WCC, we amended the 2014 Financing Agreement on July 31, 2015 to (i) allow us to make cash distributions in an aggregate amount not to exceed $15.0 million (previously $7.5 million) when our Consolidated Total Net Leverage ratio is more than 3.75 or Fixed Charge Coverage ratio is less than 1.00 (as such ratios are defined in the 2014 Financing Agreement) and (ii) at any time that we have a revolving loan facility available, require us to have liquidity of at least $7.5 million (previously $5.0 million), after giving effect to such cash distributions and applying availability under such revolving loan facility towards satisfying the liquidity requirement (“Restricted Distributions”). As of March 31, 2017, our Consolidated Total Net Leverage ratio is in excess of 3.75, our Fixed Charge Coverage ratio is below 1.0, and we have made $14.4 million in Restricted Distributions.
As of March 31, 2017, we were in compliance with all covenants under the terms of the 2014 Financing Agreement.
Revolving Credit Facility
On October 23, 2015, the Partnership and its subsidiaries entered into a loan and security agreement (the “Revolving Credit Facility”) with the lenders party thereto and The PrivateBank and Trust Company, as administrative agent, which permits borrowings up to the aggregate principal amount of $15.0 million, subject to borrowing base calculations as defined in the agreement and letters of credit in an aggregate outstanding amount of up to $10.0 million, which reduces availability under the Revolving Credit Facility on a dollar-for-dollar basis. The Revolving Credit Facility contains the same terms as the 2014 Financing Agreement regarding Restricted Distributions. At March 31, 2017, availability under the Revolving Credit Facility was $14.7 million.
Capital Leases
We did not enter into any new capital leases during the three months ended March 31, 2017.
6. DISTRIBUTIONS OF AVAILABLE CASH
We distribute 100% of our available cash within 45 days after the end of each quarter to unitholders of record and to our GP, subject to the conditions and limitations within the 2014 Financing Agreement and the Revolving Credit Facility. Available cash is determined at the end of each quarter and is generally defined in the Partnership’s Fourth Amended and Restated Agreement of Limited Partnership, as amended (the "Partnership Agreement") as all cash and cash equivalents on hand at the end of each quarter less reserves established by our GP in its reasonable discretion for future cash requirements. These reserves are retained to provide for the conduct of our business, the payment of debt principal and interest and to provide funds for future distributions for any one or more of the next four quarters, and to comply with applicable law. Our available cash may also include, if our GP so determines, all or any portion of the cash on hand on the date of determination of available cash for the quarter resulting from working capital borrowings made subsequent to the end of such quarter.

We made cash distributions as follows (in thousands):
 
Three Months Ended March 31,
 
2017
 
2016
Limited Partner common units
$
163

 
$
1,142

General Partner units
5

 
8

Warrants
22

 
33

    
Both our 2014 Financing Agreement and Revolving Credit Facility restrict us from making cash distributions in excess of $15.0 million in the aggregate when certain ratios and liquidity requirements are not met. As of March 31, 2017, these ratios are not met, and we do not foresee them being met in the near future. As of March 31, 2017, we have distributed $14.4 million in cash that counts toward the $15.0 million in aggregate Restricted Distribution payments. On April 27, 2017, we announced a quarterly cash distribution for the quarter ended March 31, 2017, of $0.1333 per limited partner common unit, general partner unit and warrant with distribution rights. Additionally, we declared a paid-in-kind unit distribution of $0.1333 per Series A Convertible Unit. The cash distribution totaling approximately $0.2 million, was payable to all common unitholders and warrant holders on May 15, 2017 to all common unitholders and warrant holders of record as of May 11, 2017, which record date was revised via press release on May 1, 2017.

7. FAIR VALUE MEASUREMENTS

10
WESTMORELAND RESOURCE PARTNERS, LP AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

The book values of cash, accounts receivable and accounts payable are considered to be representative of their respective fair values because of the immediate short-term maturity of these financial instruments.

In connection with our refinancing in June 2013, certain of the second lien lenders and lender affiliates received warrants entitling them to purchase common units. The warrants are measured at fair value at each balance sheet date. As of March 31, 2017, the fair value of each warrant was $4.68, based on the following: spot price of $4.80 per unit as traded on the New York Stock Exchange, with an exercise price of $0.12 per unit. The fair value of the warrants are a Level 1 measurement.

See Note 3. Restricted Investments to the consolidated financial statements (unaudited) for additional disclosures related to fair value measurements of restricted investments.

8. UNIT-BASED COMPENSATION

We grant employees and non-employee directors restricted common units under our Long-Term Incentive Plan (“LTIP”). We recognized compensation expense from unit-based arrangements shown in the following table:
 
Three Months Ended March 31,
 
2017
 
2016
 
(In thousands)
Recognition of fair value of restricted common units over the vesting period
$
42

 
$
64

A summary of restricted common unit award activity for the three months ended March 31, 2017 is as follows:
 
Units
 
Weighted Average Grant-Date Fair Value
 
Unamortized Compensation Expense
Unvested balance at December 31, 2016
63,780

 
$
3.92

 
 
Granted
—

 
—

 
 
Vested
(63,780
)
 
3.92

 
 
Unvested balance at March 31, 2017
—

 
$
—

 
$
—


9. COMMITMENTS AND CONTINGENCIES
Coal Sales Contracts

We are committed under long-term contracts to sell coal that meets certain quality requirements at specified prices. Many of these prices are subject to cost pass-through or cost adjustment provisions that mitigate some risk from rising costs. Quantities sold under some of these contracts may vary from year to year within certain limits at the option of the customer or us. As of March 31, 2017, the remaining terms of our long-term contracts range from one to nine years.

Purchase Commitments 

In April 2016, we entered into a fixed price agreement to purchase 1.0 million tons of coal from a third party through December 31, 2017. Through March 31, 2017 we have purchased 0.6 million coal tons under the purchase commitment.

From time to time, we purchase coal from third parties in order to meet quality or delivery requirements under our customer contracts. We buy coal on the spot market, and the cost of that coal is dependent upon the market price and quality of the coal.

Litigation

There have been no material changes in our litigation since December 31, 2016. For additional information, refer to Note 21. Commitments and Contingencies to the consolidated financial statements of our 2016 Form 10-K.


11
WESTMORELAND RESOURCE PARTNERS, LP AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

Guarantees

Our GP and the Partnership guarantee certain obligations of our subsidiaries. We believe that these guarantees will expire without any liability to the guarantors, and therefore will not have a material adverse effect on our financial position, liquidity or operations.

10. PARTNERS' CAPITAL AND CONVERTIBLE UNITS
Our capital accounts are comprised of approximately 0.16% beneficial general partner interests and 99.84% limited partner interests as of March 31, 2017. Our limited partners have limited rights of ownership as provided for under our Partnership Agreement and the right to participate in our distributions. Our General Partner manages our operations and participates in our distributions, including certain incentive distributions pursuant to the incentive distribution rights, which are nonvoting limited partner interests held by our GP. Pursuant to our Partnership Agreement, our General Partner participates in losses and distributions based on its interest. The General Partner’s participation in the allocation of losses and distributions is not limited and therefore, such participation can result in a deficit to its capital account. Allocation of losses and distributions, including distributions for previous transactions between entities under common control, has resulted in a deficit to certain limited partners’ capital accounts included in our consolidated balance sheets.
Series A Convertible Units
WCC, the owner of our General Partner, holds and participates in distributions on our Series A Convertible Units. Series A Convertible Units have the right to share in distributions from us on a pro-rata basis with the common units. All or any portion of each distribution payable in respect of the Series A Convertible Units (the “Series A Convertible Unit Distribution”) may, at our Board of Directors’ election, be paid in Series A paid-in-kind Units (“Series A PIK Units”). To the extent any portion of the Series A Convertible Unit Distribution is paid in Series A PIK Units for any quarter, the distribution to the holders of incentive distribution rights shall be reduced by that portion of the distribution that is attributable to the payment of those Series A PIK Units. The Series A Convertible Units will convert into common units, on a one-for-one basis, at the earlier of the date on which we first make a regular quarterly cash distribution with respect to any quarter to holders of common units in an amount at least equal to $0.22 per common unit or upon a change of control. The Series A Convertible Units have the same voting rights as if they were outstanding common units and will vote together with the common units as a single class. In addition, the Series A Convertible Units are entitled to vote as a separate class on any matters that materially adversely affect the rights or preferences of the Series A Convertible Units in relation to other classes of partnership interests or as required by law.
Series B Convertible Units
On October 28, 2016, we issued 4,512,500 Series B Convertible Units representing limited partner interests in the Partnership (the “Series B Units”) to WCC in exchange for WCC’s 4,512,500 common units (the “Exchange”). Upon issuance of the Series B Units in the Exchange, WCC’s common units were canceled. The Series B Units do not share in distributions with the common units and are convertible at the option of the holder on a one-for-one basis into common units on the day after the record date for a cash distribution on the common units in which the Partnership is unable to make such a distribution without exceeding its restricted payment basket under the 2014 Financing Agreement. The Series B Units will convert automatically upon a change of control or a dissolution or liquidation of the Partnership. The Series B Units have the same voting rights as if they were outstanding common units and will vote together with the common units as a single class. In addition, the Series B Units are entitled to vote as a separate class on any matters that materially adversely affect the rights or preferences of the Series B Units in relation to other classes of partnership interests or as required by law. Concurrently with the Exchange, we entered into Amendment No. 2 to the Partnership Agreement, which established the terms of the Series B Units.
Liquidation Units
All subordinated units were transferred to WCC in connection with our GP being acquired on December 31, 2014. These units were then converted to liquidation units which have no distribution or voting rights, other than in connection with liquidation. For tax purposes, liquidation units are allocated additional taxable income but no additional taxable loss compared to other unit classes.
Warrants
In June 2013, in connection with a prior credit facility, certain lenders and lender affiliates received warrants entitling them to purchase 166,557 common units at $0.12 per unit. The warrants participate in distributions whether or not exercised.

12
WESTMORELAND RESOURCE PARTNERS, LP AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

Outstanding Units
 
March 31, 2017
 
December 31, 2016
Limited partner common units
1,284,840

 
1,221,060

Series A Units
16,215,029

 
15,656,551

Series B Units
4,512,500

 
4,512,500

Liquidation units
856,698

 
856,698

Warrants
166,557

 
166,557

General Partner units
35,291

 
35,291

Net Income (Loss) attributable to limited partners
Net income (loss) is allocated to the GP and the limited partners in accordance with their respective ownership percentages, after giving effect to distributions and declared distributions on Series A Convertible Units, and General Partner units, including incentive distribution rights. Unvested unit-based payment awards that contain non-forfeitable rights to distributions (whether paid or unpaid) are classified as participating securities and are included in our computation of basic and diluted limited partners’ net income (loss) per common unit. Basic and diluted limited partners’ net income (loss) per common unit is calculated by dividing limited partners’ interest in net income (loss) by the weighted average number of outstanding limited partner units during the period. We determined basic and diluted limited partners’ net loss per common unit as follows (in thousands, except per unit amounts):
 
Three Months Ended March 31,
 
2017
 
2016
Net loss attributable to the Partnership
$
(8,815
)
 
$
(8,856
)
Less:
 
 
 
Paid and declared distributions on Series A convertible units
2,162

 
3,131

Series A convertible units share of undistributed loss
(8,229
)
 
(9,535
)
Paid and declared distributions on Series B convertible units
—

 
—

Series B convertible units share of undistributed loss
(2,292
)
 
—

Paid and declared distributions on General Partner units
5

 
7

General Partner units share of undistributed loss
(18
)
 
(22
)
Paid and declared distributions on Warrants
22

 
33

Net loss available to limited partners
$
(465
)
 
$
(2,470
)
 
 
 
 
Weighted average number of common units used in computation of Limited Partners' net loss per common unit (basic and diluted)1,2
1,451

 
5,885

Limited Partners' net loss per common unit (basic and diluted)
$
(0.32
)
 
$
(0.41
)
____________________ 
1 Unvested LTIP units are not dilutive units for the periods presented herein, but could be in the future. Anti-dilutive units are not used in calculating diluted average units.
2 Reflects the impact of the outstanding common unit warrants for the three months ended March 31, 2017 and 2016, respectively.    
11. ACCUMULATED OTHER COMPREHENSIVE LOSS
The following table reflects the changes in accumulated other comprehensive loss arising from our available-for-sale securities (net of tax):
 
Accumulated Other Comprehensive Loss
 
(In thousands)
Balance at December 31, 2016
$
(189
)
Other comprehensive loss before reclassification
116

Amounts reclassified from accumulated other comprehensive loss
30

Balance at March 31, 2017
$
(43
)

13
WESTMORELAND RESOURCE PARTNERS, LP AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)


The following table reflects the reclassifications out of accumulated other comprehensive loss for the three months ended March 31, 2017:
 
 
 
Amount reclassified from accumulated other comprehensive loss
 
Affected line item in the statement where net loss is presented
 
Details about accumulated other comprehensive loss components
 
Three Months Ended March 31, 2017
 
 
 
 
(In thousands)
 
 
Realized gains and losses on available-for-sale securities
 
$
30

 
Other income

    
12. RELATED PARTY TRANSACTIONS
In 2015, the Partnership and the GP entered into an administrative and operational services agreement (the “Services Agreement”). The Services Agreement is terminable by either party upon 120 days’ written notice prior to the end of any fiscal year. Under the terms of the Services Agreement, our GP provides services through its employees, or employees of its affiliates, to us and is reimbursed for all related costs incurred on our behalf. Pursuant to the Services Agreement, the Partnership engaged the GP to continue providing services such as general administrative and management, engineering, operations (including mining operations), geological, corporate development, real property, marketing, and other services to the Partnership. Administrative services include without limitation legal, finance and accounting, treasury, insurance administration and claims processing, risk management, health, safety and environmental, information technology, human resources, credit, payroll, internal audit and tax. Under the Services Agreement the Partnership pays the GP a fixed annual management fee of $2.2 million for certain executive and administrative services, and reimburses the GP at cost for other expenses and expenditures. The current terms of the Services Agreement expires on December 31, 2017, and automatically renews for successive one year periods unless terminated. The primary reimbursements to our GP under the Service Agreement during the three months ended March 31, 2017 were for employee-related costs. Reimbursable costs under the Services Agreement totaling $0.9 million and $2.7 million were included in accounts payable as of March 31, 2017 and December 31, 2016, respectively. In December 2016, the Partnership prepaid the GP for the 2017 annual management fee of $2.2 million, of which $1.6 million was included in Other current assets at March 31, 2017.
On January 9, 2017 the Partnership acquired surface coal reserves ("Johnson Run") through conveyance of leases and recoupable advance royalty payments from Buckingham Coal Company, LLC, a wholly owned subsidiary of WCC, for $1.7 million.
Finally, we sold coal to a subsidiary of WCC, which generated $3.8 million in coal revenues for the three months ended March 31, 2017.
13. SEGMENT INFORMATION
We operate in one business segment. We operate surface coal mines in Ohio and Wyoming, selling high-value thermal coal to utilities, industrial customers, municipalities and other coal-related entities primarily in the Midwest and Wyoming. All of our operations have similar economic characteristics including but not limited to coal quality, geology, coal marketing opportunities, mining and transportation methods and regulatory issues. Our operating and executive management makes its decisions based on consolidated reports. Our Ohio operating subsidiaries share customers and a particular customer may receive coal from any one of such Ohio operating subsidiaries. We also lease or sublease coal reserves to others through our Ohio operations in exchange for a per ton royalty rate.
14. SUBSEQUENT EVENTS
The Partnership has evaluated subsequent events in accordance with ASC 855, Subsequent Events, through the filing date of its Quarterly Report on Form 10-Q, and determined that there have been no events that have not been disclosed elsewhere in the Notes to the Consolidated Financial Statements (Unaudited) that have occurred that would require adjustments to disclosures in the consolidated financial statements (unaudited).

14

Item 2 - MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The following discussion and analysis of our financial condition and results of operations should be read in conjunction with the consolidated financial statements (unaudited) and notes thereto included elsewhere in this Quarterly Report on Form 10-Q and the audited consolidated financial statements and notes thereto and management’s discussion and analysis of financial condition and results of operations for the year ended December 31, 2016 included in our 2016 Form 10-K and filed with the United States Securities and Exchange Commission (the “SEC”). This discussion contains forward-looking statements that reflect management’s current views with respect to future events and financial performance. Our actual results may differ materially from those anticipated in these forward-looking statements or as a result of certain factors such as those set forth below under “Cautionary Note Regarding Forward-Looking Statements.”
Cautionary Note Regarding Forward-Looking Statements
This Quarterly Report on Form 10-Q and other materials we have filed or will file with the SEC (as well as information included in our other written or oral statements) contain or will contain certain statements that are forward-looking within the meaning of the Private Securities Litigation Reform Act of 1995. These statements are based on our expectations and assumptions at the time they are made and are not guarantees of future performance. Because forward looking statements relate to the future, they involve certain risks, uncertainties and assumptions that are difficult to predict. Actual outcomes and results may differ materially from those expressed in, or implied by, our forward-looking statements. Words such as “expects,” “intends,” “anticipates,” “believes,” “estimates,” “guides,” “provides guidance,” “provides outlook” and other similar expressions or future or conditional verbs such as “may,” “will,” “should,” “would,” “could,” and “might” are intended to identify such forward-looking statements. Readers of this quarterly report should not rely solely on the forward-looking statements and should consider all uncertainties and risks discussed in the “Risk Factors” section and throughout this Quarterly Report on Form 10-Q. The statements are only as of the date they are made, and the Partnership undertakes no obligation to update any forward-looking statement. Possible events or factors that could cause results or performance to differ materially from those expressed in our forward-looking statements include but are not limited to the following:
•
The effect of legal and administrative proceedings, settlements, investigations and claims, including any related to citations and orders issued by regulatory authorities, and the availability of related insurance coverage;
•
Existing and future legislation and regulation affecting both our coal mining operations and our customers’ coal usage, governmental policies and taxes, including those aimed at reducing emissions of elements such as mercury, sulfur dioxides, nitrogen oxides, particulate matter or greenhouse gases;
•
The effect of the Environmental Protection Agency’s inquiries and regulations on the operations of the power plants to which we provide coal;
•
Our substantial level of indebtedness and our ability to adhere to financial covenants related to our borrowing     arrangements;
•
Inaccuracies in our estimates of our coal reserves;
•
Our potential inability to expand or continue current coal operations due to limitations in obtaining bonding capacity for new mining permits, and/or increases in our mining costs as a result of increased bonding expenses;
•
The effect of prolonged maintenance or unplanned outages at our operations or those of our major power generating customers;
•
The inability to control costs and/or recognize favorable tax credits
•
Competition within our industry and with producers of competing energy sources;
•
Our relationships with, and other conditions affecting, our customers, including how power prices affect our customers’ decision to run their plants;
•
Seasonal variations and inclement weather which may cause fluctuations in our operating results, profitability, cash flow and working capital needs related to our operating segments;
•
The availability and costs of key supplies or commodities, such as diesel fuel, steel and explosives;
•
Potential title defects or loss of leasehold interests in our properties, which could result in unanticipated costs or an inability to mine the properties;
•
The effect of consummating financing, acquisition and/or disposition transactions;
•
The inability to renew our mineral leases or material changes in lease royalties;
•
Our ability to pay our quarterly distributions which substantially depends upon our future operating performance (which may be affected by prevailing economic conditions in the coal industry), debt covenants, and financial, business and other factors, some of which are beyond our control. Additional information is found in our discussion below under Cash Distributions;
•
Our potential need to recognize additional impairment and/or restructuring expenses associated with our operations, as well as any changes to previously identified impairment or restructuring expense estimates; and

15

•
Other factors that are described under the heading “Risk Factors” found in our reports filed with the SEC, including our Annual Reports on Form 10-K and our Quarterly Reports on Form 10-Q.
Overview
We sell almost all of our coal under multi-year agreements to electric generation companies. These contracts often contain price escalation and adjustment provisions, pursuant to which the price for our coal may be periodically revised in line with broad economic indicators such as the consumer price index, commodity-specific indices such as the PPI-light fuel oils index, and/or changes in our actual costs. For our contracts that are not cost protected in nature, we have exposure to inflation and price risk for supplies used in the normal course of production such as diesel fuel and explosives. We manage these items through strategic sourcing contracts in normal quantities with our suppliers and may use derivatives from time-to-time.
One of the major factors affecting the volume of coal that we sell in any given year is the demand for coal-generated electric power, as well as the specific demand for coal by our customers. Numerous factors affect the demand for electric power and the specific demands of customers including weather patterns, the presence of hydro- or wind-generated energy in our particular energy grids, environmental and legal challenges, political influences, energy policies, international and domestic economic conditions, power plant outages and other factors discussed herein.
Results of Operations 
Three Months Ended March 31, 2017 Compared to Three Months Ended March 31, 2016
Overview
 
Three Months Ended March 31,
 
Increase / (Decrease)
 
2017
 
2016
 
$
 
%
 
(In millions)
Total Revenues
$
74.8

 
$
92.5

 
$
(17.7
)
 
(19.1
)%
Net loss
(8.8
)
 
(8.9
)
 
0.1

 
1.1
 %
Adjusted EBITDA1
12.9

 
19.3

 
(6.4
)
 
(33.2
)%
____________________
1Adjusted EBITDA, a non-GAAP measure, is defined and reconciled to net income (loss) at the end of this “Results of Operations” section.

The revenue decrease of $17.7 million was driven by difficult weather conditions in Wyoming and difficult market conditions in Ohio. Despite these revenue decreases, our net loss remained relatively unchanged due to strong cost controls and decreases in depreciation, depletion, and amortization expense. Adjusted EBITDA declined as the decreases in depreciation, depletion, and amortization expense do not impact this metric. These results are discussed in more detail below.
Coal and Non-Coal Revenues
 
Three Months Ended March 31,
 
Increase / (Decrease)
 
2017
 
2016
 
$
 
%
 
(In millions)
Coal revenues
$
73.1

 
$
91.6

 
$
(18.5
)
 
(20.2
)%
Non-coal revenues
1.7

 
0.9

 
0.8

 
88.9
 %
Total Revenues
$
74.8

 
$
92.5

 
$
(17.7
)
 
(19.1
)%

The Coal revenues decrease of $18.5 million, or 20.2%, for the three months ended March 31, 2017 was primarily attributable to a 17.1% decrease in tons sold in the amount of $15.7 million, compounded by a $1.59 per ton, or an aggregate $2.8 million, decrease in the average sales price per ton for the three months ended March 31, 2017. Volumes were pressured in Wyoming due to unusually high amounts of precipitation, which restricted our ability to supply coal. Weather conditions are inherently unpredictable and could have positive or negative impacts on mining conditions in future periods. Volumes and pricing were pressured in Ohio due to a challenging coal market. Whether pricing and volume softness in this region persist in future periods is dependent upon fluctuations in market demand in the region. 

Non-coal revenues, primarily from limestone sales, non-coal services and other miscellaneous revenue increased $0.8 million for the three months ended March 31, 2017 primarily attributable to a $0.6 million increase in oil and gas royalties compounded by a $0.2 million increase in limestone sales.

16


Cost and Expenses
 
Three Months Ended March 31,
 
Increase / (Decrease)
 
2017
 
2016
 
$
 
%
 
(In millions)
Cost of coal revenues
$
59.3

 
$
71.2

 
$
(11.9
)
 
(16.7
)%
Depreciation, depletion and amortization
10.4

 
15.3

 
(4.9
)
 
(32.0
)%
Selling and administrative
3.9

 
3.3

 
0.6

 
18.2
 %

Cost of coal revenues (excluding depreciation, depletion and amortization (“DD&A”)) decreased $11.9 million for the three months ended March 31, 2017. The decrease was primarily attributable to a 0.4 million decrease in tons sold, which corresponds to a $12.2 million decrease in cost of coal revenues, offset in part by an increase in the cost to produce coal of $0.17 per ton, or an aggregate $0.3 million, for the three months ended March 31, 2017.

DD&A expense decreased $4.9 million for the three months ended March 31, 2017, comprised of a $3.0 million decrease in amortization expense compounded by a $1.3 million and $0.6 million decrease in depreciation expense and depletion, respectively, for the three months ended March 31, 2017. The decrease in DD&A is due to the decreased volumes of coal deliveries as well as lower depreciation expense as a result of a smaller and aging fleet at our Ohio operations.

Nonoperating Results (including interest expense, interest income, and change in fair value of warrants)
 
Three Months Ended March 31,
 
Increase / (Decrease)
 
2017
 
2016
 
$
 
%
 
(In millions)
Interest expense
$
10.5

 
$
9.8

 
$
0.7

 
7.1
 %
Interest income
0.2

 
0.3

 
(0.1
)
 
(33.3
)%
Change in fair value of warrants
0.1

 
(0.2
)
 
0.3

 
*

____________________
* Not meaningful.

Nonoperating results were consistent period-over-period.
Non-GAAP Financial Measures
Adjusted EBITDA

EBITDA and Adjusted EBITDA are supplemental measures of financial performance that are not required by, or presented in accordance with, United States GAAP. EBITDA and Adjusted EBITDA are key metrics used by us to assess our operating performance, and we believe that EBITDA and Adjusted EBITDA are useful to an investor in evaluating our operating performance because these measures:
•
are used widely by investors to measure a company’s operating performance without regard to items excluded from the calculation of such terms, which can vary substantially from company to company depending upon accounting methods and book value of assets, capital structure and the method by which assets were acquired, among other factors;
•
are used by rating agencies, lenders and other parties to evaluate our creditworthiness; and
•
help investors to more meaningfully evaluate and compare the results of our operations from period to period by removing the effect of our capital structure and asset base from our operating results.
Neither EBITDA nor Adjusted EBITDA is a measure calculated in accordance with GAAP. The items excluded from EBITDA and Adjusted EBITDA are significant in assessing our operating results. EBITDA and Adjusted EBITDA have limitations as analytical tools, and should not be considered in isolation from, or as a substitute for, analysis of our results as reported under GAAP. For example, EBITDA and Adjusted EBITDA:
•
do not reflect our cash expenditures or future requirements for capital and major maintenance expenditures or contractual commitments;
•
do not reflect changes in, or cash requirements for, our working capital needs; and

17

•
do not reflect the significant interest expense, or the cash requirements necessary to service interest or principal payments, on certain of our debt obligations.
In addition, although depreciation and amortization are non-cash charges, the assets being depreciated and amortized will often have to be replaced in the future, and EBITDA and Adjusted EBITDA do not reflect any cash requirements for such replacements. Other companies in our industry and in other industries may calculate EBITDA and Adjusted EBITDA differently from the way that we do, limiting their usefulness as comparative measures. Because of these limitations, EBITDA and Adjusted EBITDA should not be considered as measures of discretionary cash available to us to invest in the growth of our business. We compensate for these limitations by relying primarily on our GAAP results and using EBITDA and Adjusted EBITDA only as supplemental data.
Distributable Cash Flow

Distributable Cash Flow represents Adjusted EBITDA less cash changes in deferred revenue, cash reclamation and mine closure expenditures, reserve replacement and maintenance capital expenditures, cash pension and postretirement medical expenditures, and cash interest expense (net of interest income). Cash interest expense represents the portion of our interest expense accrued and paid in cash during the reporting periods presented or that we will pay in cash in future periods as the obligations become due. Other maintenance capital expenditures represent expenditures for coal reserve replacement, and for plant, equipment and mine development. Cash reclamation expenditures represent the reduction to our reclamation and mine closure costs resulting from cash payments. Earnings attributable to the noncontrolling interest are not available for distribution to our unitholders and accordingly are deducted.

Distributable Cash Flow should not be considered as an alternative to net income (loss) attributable to our unitholders, income from operations, cash flows from operating activities or any other measure of performance presented in accordance with GAAP. Although Distributable Cash Flow is not a measure of performance calculated in accordance with GAAP, we believe Distributable Cash Flow is useful to investors because this measurement is used by many analysts and others in the industry as a performance measurement tool to evaluate our operating and financial performance, facilitating comparison with the performance of other publicly traded limited partnerships.
The tables below show how we calculated EBITDA, Adjusted EBITDA and Distributable Cash Flow and reconcile EBITDA, Adjusted EBITDA and Distributable Cash Flow to Net Loss, the most directly comparable GAAP financial measure. 

18

Reconciliation of Net Loss to Distributable Cash Flow
 
Three Months Ended March 31,
 
2017
 
2016
 
(In thousands)
Reconciliation of Adjusted EBITDA to Net Loss
 
 
 
Net loss
$
(8,815
)
 
$
(8,856
)
Interest expense, net of interest income
10,273

 
9,508

Depreciation, depletion and amortization
10,351

 
15,265

Accretion of ARO
1,335

 
1,375

EBITDA
13,144

 
17,292

Impairment charges
—

 
538

Loss (gain) on sale of assets
(142
)
 
1,229

Share-based compensation
42

 
64

Other non-cash and non-recurring costs1
(175
)
 
166

Adjusted EBITDA
12,869

 
19,289

Deferred revenue
2,446

 
3,572

Reclamation and mine closure costs
(1,873
)
 
(1,888
)
Maintenance capital expenditures and other capitalized items
(3,151
)
 
(1,545
)
Cash interest expense, net of interest income
(7,222
)
 
(6,712
)
Other
—

 
(1,020
)
Distributable Cash Flow
$
3,069

 
$
11,696

____________________
1 Includes non-cash activity from the change in fair value of investments and warrants.

Liquidity and Capital Resources 
Liquidity 

We had the following liquidity at March 31, 2017 and December 31, 2016:
 
March 31, 2017
 
December 31, 2016
 
(In millions)
Cash and cash equivalents
$
20.2

 
$
15.1

Availability under the Revolving Credit Facility
14.7

 
15.0

Total
$
34.9

 
$
30.1

We anticipate that our cash from operations, cash on hand and available borrowing capacity will be sufficient to meet our investing, financing, and working capital requirements for the foreseeable future.
Our business is capital intensive and requires substantial capital expenditures for, among other things, purchasing, maintaining and upgrading equipment used in developing and mining our coal, and acquiring reserves. Our principal liquidity needs are to finance current operations, replace reserves, fund capital expenditures, including costs of acquisitions from time to time, service our debt and pay quarterly cash distributions to our unitholders. Our primary sources of liquidity to meet these needs have been cash generated by our operations, borrowings under the 2014 Financing Agreement, and availability under our Revolving Credit Facility.
Our ability to satisfy our working capital requirements, meet debt service obligations and fund planned capital expenditures substantially depends upon our future operating performance, which may be affected by prevailing economic conditions in the coal industry. To the extent our future operating cash flow or access to financing sources and the costs thereof are materially different than expected, our future liquidity may be adversely affected.

19

Debt Obligations 

See Note 5. Debt And Lines Of Credit to the consolidated financial statements (unaudited) for a description of our debt and available lines of credit.

As of March 31, 2017, the outstanding balance on our 2014 Financing Agreement was $308.1 million. This amount represents the principal balance of $289.7 million, plus PIK interest of $18.4 million as of March 31, 2017. As of March 31, 2017, our 2014 Financing Agreement had a cash interest rate of 9.65%, consisting of the LIBOR (1.15%) plus 8.50%. Additionally, as of March 31, 2017, availability under the Revolving Credit Facility was $14.7 million

Cash Distributions 

Our Partnership Agreement requires that we distribute all of our available cash quarterly subject to certain restrictions under our 2014 Financing Agreement and our Revolving Credit Facility described further below. Under our Partnership Agreement, available cash is determined at the end of each quarter and generally defined as cash generated from our business in excess of the amount of cash reserves established by our general partner to provide for the conduct of our business, to comply with applicable law, to make payments related to any of our debt instruments or other agreements, or to provide for future distributions to our unitholders for any one or more of the next four quarters. Our available cash may also include, if our general partner so determines, all or any portion of the cash on hand on the date of determination of available cash for the quarter resulting from working capital borrowings made subsequent to the end of such quarter.

Both our 2014 Financing Agreement and Revolving Credit Facility restrict us from making cash distributions in excess of $15.0 million in the aggregate when certain ratios and liquidity requirements are not met, see Note 5. Debt And Lines Of Credit to the consolidated financial statements (unaudited). As of March 31, 2017, these ratios are not met, and we do not foresee them being met in the near future.

As of March 31, 2017, we have distributed $14.4 million in cash that counts toward the $15.0 million in aggregate Restricted Distribution payments. On April 27, 2017, we announced a quarterly cash distribution for the quarter ended March 31, 2017, of $0.1333 per common unit, warrant with distribution rights and a distribution of Series A PIK Units in lieu of a cash distribution for holders of Series A Convertible Units (“First Quarter Distribution”). The First Quarter Distribution, totaling cash of approximately $0.2 million, will be paid on May 15, 2017 to all common unitholders and warrant holders of record as of May 11, 2017. The First Quarter Distribution will bring the aggregate remaining permitted Restricted Distributions total to $0.4 million at that time. If we are unable to refinance or modify our Term Loan, we are only permitted to make $0.4 million in additional Restricted Distributions subsequent to payment of the First Quarter Distribution.

Historical Sources and Uses of Cash

The following table summarizes net cash provided by (used in) operating, investing and financing activities for the three months ended March 31, 2017 and 2016:
 
Three Months Ended March 31,
 
2017
 
2016
 
(In thousands)
Net cash provided by (used in):
 
 
 
Operating activities
$
11,220

 
$
10,927

Investing activities
(3,305
)
 
(3,854
)
Financing activities
(2,775
)
 
(2,124
)
Net cash provided by (used in) operating, investing and financing activities were consistent period-over-period.
Capital Expenditures

Our mining operations require investments to maintain, expand, and upgrade existing operations and to meet environmental and safety regulations. We have funded and expect to continue funding capital expenditures primarily from cash generated by our operations, borrowings under the 2014 Financing Agreement, and proceeds from asset sales. In the future, we may also fund capital expenditures with borrowings under the Revolving Credit Facility.


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The following table summarizes our capital expenditures by type for the three months ended March 31, 2017, and 2016:
 
Three Months Ended March 31,
 
2017
 
2016
 
(In thousands)
Coal reserves
$
—

 
$
—

Mine development
35

 
180

Equipment and components
2,725

 
1,364

Total
$
2,760

 
$
1,544


Critical Accounting Policies and Estimates

Please refer to the corresponding section in Part II - Item 7 - Management's Discussion and Analysis of Financial Condition and Results of Operations of our 2016 Form 10-K for a discussion of our accounting policies and estimates.

Recent Accounting Pronouncements
See Note 1. Basis Of Presentation to the consolidated financial statements (unaudited).
Off-Balance Sheet Arrangements

In the normal course of business, we are a party to certain off-balance sheet arrangements. These arrangements include financial instruments with off-balance sheet risk such as bank letters of credit and performance or surety bonds. We utilize surety bonds and letters of credit issued by financial institutions to third parties to assure the performance of our obligations relating to reclamation, workers’ compensation obligations, postretirement medical benefit obligations, and other obligations. These arrangements are not reflected in our consolidated balance sheets, and we do not expect any material adverse effects on our financial condition, results of operations or cash flows to result from these off-balance sheet arrangements.
There have been no material changes to our off-balance sheet arrangements since December 31, 2016. Our off-balance sheet arrangements are discussed in Part II - Item 7 - Management's Discussion and Analysis of Financial Condition and Results of Operations of our 2016 Form 10-K.
Item 3 - QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
There have been no material changes in our market risk since December 31, 2016. For additional information, refer to Part II - Item 7A - Quantitative and Qualitative Disclosures about Market Risk of our 2016 Form 10-K.
Item 4 - CONTROLS AND PROCEDURES


Changes in Internal Control over Financial Reporting

Beginning January 1, 2017, the Partnership implemented a new enterprise resource planning (“ERP”) system which will improve the timeliness and quality of information (including financial information) to all appropriate levels of Partnership personnel. The integration was not in response to any identified deficiency or material weakness in the Partnership’s internal control over financial reporting. The integration of the ERP system will likely affect the processes included in our internal controls over financial reporting and will require testing for operating effectiveness.

Also beginning January 1, 2017 and in connection with the implementation of the new ERP system discussed immediately above, the Partnership initiated the centralization of controls from our local office in Coshocton, Ohio to the Partnership’s corporate offices in Englewood, CO. The centralization was not in response to any identified deficiency or material weakness in the Partnership’s internal controls over financial reporting. The centralization will be completed throughout 2017 and will affect the processes that constitute our internal controls over financial reporting. The centralized control framework will require testing for operating effectiveness.




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PART II
OTHER INFORMATION

Item 1 - LEGAL PROCEEDINGS
We are subject, from time-to-time, to various proceedings, lawsuits, disputes, and claims (“Actions”) arising in the ordinary course of our business. Many of these Actions raise complex factual and legal issues and are subject to uncertainties. We cannot predict with assurance the outcome of Actions brought against us. Accordingly, adverse developments, settlements, or resolutions may occur and may result in a negative impact on income in the quarter of such development, settlement, or resolution. However, we do not believe that the outcome of any current Action would have a material adverse effect on our financial results. See Note 9. Commitments And Contingencies to the consolidated financial statements (unaudited) for a description of any pending legal proceedings, which information is incorporated herein by reference.
Item 1A - RISK FACTORS
We have disclosed under the heading “Risk Factors” in our 2016 Form 10-K, the risk factors that we believe materially affect our business, financial condition or results of operations. There have been no material changes from the risk factors previously disclosed. You should carefully consider the risk factors set forth in the 2016 Form 10-K and the other information set forth elsewhere in this Quarterly Report on Form 10-Q. You should be aware that these risk factors and other information may not describe every risk that 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 and or operating results.
Item 4 - MINE SAFETY DISCLOSURES
On July 21, 2010, Congress enacted the Dodd-Frank Wall Street Reform and Consumer Protection Act (the “Dodd-Frank Act”). Section 1503(a) of the Dodd-Frank Act contains reporting requirements regarding mine safety. Mine safety violations or other regulatory matters, as required by Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K, are included as Exhibit 95.1 to this report on Form 10-Q.
Item 6 - EXHIBITS
The exhibits listed in the Exhibit Index are incorporated herein by reference.

 

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SIGNATURES
   Pursuant to the requirements 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.

 
 
WESTMORELAND RESOURCE PARTNERS, LP
 
 
By: 
WESTMORELAND RESOURCES GP, LLC, its general partner  
 
 
 
 
Date:
May 15, 2017
By: 
/s/ Nathan M. Troup
 
 
 
Nathan M. Troup
 
 
 
Interim Chief Financial Officer
 
 
 
(Principal Financial Officer and A Duly Authorized Officer)  




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Index to Exhibits
 
 
 
 
Incorporated by Reference
 
 
Exhibit Number
 
Exhibit Description
 
Form
 
File Number
 
Exhibit
 
Filing Date
 
Filed Herewith
31.1
 
Certification of Chief Executive Officer pursuant to Rule 13a-14(a)
 
 
 
 
 
 
 
 
 
X
31.2
 
Certification of Chief Financial Officer pursuant to Rule 13a-14(a)
 
 
 
 
 
 
 
 
 
X
32
 
Certifications of Chief Executive Officer and Chief Financial Officer pursuant to 18 U.S.C. Section 1350
 
 
 
 
 
 
 
 
 
X
95.1
 
Mine Safety Disclosure
 
 
 
 
 
 
 
 
 
X
101.INS
 
XBRL Instance Document
 
 
 
 
 
 
 
 
 
X
101.SCH
 
XBRL Taxonomy Extension Schema Document
 
 
 
 
 
 
 
 
 
X
101.CAL
 
XBRL Taxonomy Calculation Linkbase Document
 
 
 
 
 
 
 
 
 
X
101.LAB
 
XBRL Taxonomy Label Linkbase Document
 
 
 
 
 
 
 
 
 
X
101.PRE
 
XBRL Taxonomy Presentation Linkbase Document
 
 
 
 
 
 
 
 
 
X
101.DEF
 
XBRL Taxonomy Definition Document
 
 
 
 
 
 
 
 
 
X

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Westmoreland Resource Partners, LP Reports