Annual Reports

 
Quarterly Reports

  • 10-Q (Nov 8, 2017)
  • 10-Q (Aug 3, 2017)
  • 10-Q (May 10, 2017)
  • 10-Q (Nov 3, 2016)
  • 10-Q (Aug 4, 2016)
  • 10-Q (May 5, 2016)

 
8-K

 
Other

Gastar Exploration 10-Q 2017

Documents found in this filing:

  1. 10-Q
  2. Ex-31.1
  3. Ex-31.2
  4. Ex-32.1
  5. Ex-32.1
gst-10q_20170930.htm

 

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

FORM 10-Q

 

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

FOR THE QUARTERLY PERIOD ENDED September 30, 2017

OR

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

FOR THE TRANSITION PERIOD FROM           TO             

Commission File Number: 001-35211

 

GASTAR EXPLORATION INC.

(Exact name of registrant as specified in its charter)

 

 

Delaware

 

38-3531640

(State or other jurisdiction of

incorporation or organization)

 

(I.R.S. Employer

Identification No.)

 

 

 

1331 Lamar Street, Suite 650

 

 

Houston, Texas

 

77010

(Address of principal executive offices)

 

(Zip Code)

(713) 739-1800

(Registrant’s telephone number, including area code)

 

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 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. 

Large accelerated filer

 

  

Accelerated filer

 

 

 

 

 

 

 

 

Non-accelerated filer

 

  (Do not check if a smaller reporting company)

  

Smaller reporting company

 

 

 

 

 

 

 

 

Emerging growth company

 

 

 

 

 

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. 

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

The total number of outstanding shares of common stock, $0.001 par value per share, as of November 6, 2017 was 218,941,521.

 

 


GASTAR EXPLORATION INC.

QUARTERLY REPORT ON FORM 10-Q

For the three and nine months ended September 30, 2017

TABLE OF CONTENTS

 

 

 

 

 

Page

PART I – FINANCIAL INFORMATION

 

 

 

Item 1.

 

Financial Statements

 

 

6

 

 

Gastar Exploration Inc. Condensed Consolidated Balance Sheets as of September 30, 2017 (unaudited) and December 31, 2016

 

 

7

 

 

Gastar Exploration Inc. Condensed Consolidated Statements of Operations for the Three and Nine Months Ended September 30, 2017 and 2016 (unaudited)

 

 

8

 

 

Gastar Exploration Inc. Condensed Consolidated Statements of Cash Flows for the Nine Months Ended September 30, 2017 and 2016 (unaudited)

 

 

9

 

 

Notes to the Condensed Consolidated Financial Statements (unaudited)

 

 

10

Item 2.

 

Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

 

33

Item 3.

 

Quantitative and Qualitative Disclosures About Market Risk

 

 

44

Item 4.

 

Controls and Procedures

 

 

45

PART II – OTHER INFORMATION

 

 

 

Item 1.

 

Legal Proceedings

 

 

46

Item 1A.

 

Risk Factors

 

 

46

Item 2.

 

Unregistered Sales of Equity Securities and Use of Proceeds

 

 

46

Item 3.

 

Defaults Upon Senior Securities

 

 

46

Item 4.

 

Mine Safety Disclosure

 

 

46

Item 5.

 

Other Information

 

 

46

Item 6.

 

Exhibits

 

 

46

SIGNATURES

 

 

48

 

 

2


 

General information about us can be found on our website at www.gastar.com. The information available on or through our website, or about us on any other website, is neither incorporated into, nor part of, this report.  Our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and other filings that we make with the U.S. Securities and Exchange Commission (“SEC”), as well as any amendments and exhibits to those reports, will be available free of charge through our website as soon as reasonably practicable after we file or furnish them to the SEC.  Information is also available on the SEC website at www.sec.gov for our U.S. filings.

 

 

 

3


Glossary of Terms

AMI

 

Area of mutual interest, an agreed designated geographic area where co-participants or other industry participants have a right of participation in acquisitions and operations

 

 

 

Bbl

 

Barrel of oil, condensate or NGLs

 

 

 

Bbl/d

 

Barrels of oil, condensate or NGLs per day

 

 

 

Bcf

 

One billion cubic feet of natural gas

 

 

 

Bcfe

 

One billion cubic feet of natural gas equivalent, calculated by converting liquids volumes on the basis of 1/6th of a barrel of oil, condensate or NGLs per Mcf

 

 

 

Boe

 

One barrel of oil equivalent determined using the ratio of six thousand cubic feet of natural gas to one barrel of oil, condensate or NGLs

 

 

 

Boe/d

 

Barrels of oil equivalent per day

 

 

 

Btu

 

British thermal unit, typically used in measuring natural gas energy content

 

 

 

FASB

 

Financial Accounting Standards Board

 

 

 

Gross acres

 

Refers to acres in which we own a working interest

 

 

 

Gross wells

 

Refers to wells in which we have a working interest

 

 

 

MBbl

 

One thousand barrels of oil, condensate or NGLs

 

 

 

MBbl/d

 

One thousand barrels of oil, condensate or NGLs per day

 

 

 

MBoe

 

One thousand barrels of oil equivalent, calculated by converting natural gas volumes on the basis of 6 Mcf of natural gas per barrel

 

 

 

MBoe/d

 

One thousand barrels of oil equivalent per day

 

 

 

Mcf

 

One thousand cubic feet of natural gas

 

 

 

Mcf/d

 

One thousand cubic feet of natural gas per day

 

 

 

Mcfe

 

One thousand cubic feet of natural gas equivalent, calculated by converting liquids volumes on the basis of 1/6th of a barrel of oil, condensate or NGLs per Mcf

 

 

 

MMBtu

 

One million British thermal units

 

 

 

MMBtu/d

 

One million British thermal units per day

 

 

 

MMcf

 

One million cubic feet of natural gas

 

 

 

MMcf/d

 

One million cubic feet of natural gas per day

 

 

 

MMcfe

 

One million cubic feet of natural gas equivalent, calculated by converting liquids volumes on the basis of 1/6th of a barrel of oil, condensate or NGLs per Mcf

 

 

 

MMcfe/d

 

One million cubic feet of natural gas equivalent per day

 

 

 

Net acres

 

Refers to our proportionate interest in acreage resulting from our ownership in gross acreage

 

 

 

Net wells

 

Refers to gross wells multiplied by our working interest in such wells

 

 

 

NGLs

 

Natural gas liquids

 

 

 

NYMEX

 

New York Mercantile Exchange

 

 

 

PBU

 

Performance based unit comprising one of our compensation plan awards

 

 

 

PUD

 

Proved undeveloped reserves

 

 

 

STACK Play

 

An acronymic name for a predominantly oil producing play referring to the exploration and development of the Sooner Trend of the Anadarko Basin in Canadian and Kingfisher Counties, Oklahoma.  References to the STACK Play is extended to adjacent counties.  

 

 

 

U.S.

 

United States of America

 

 

 

 

4


U.S. GAAP

 

Accounting principles generally accepted in the United States of America

 

 

 

WTI

 

West Texas Intermediate

 

 

5


PART I. FINANCIAL INFORMATION

 

Item 1. Financial Statements


 

6


GASTAR EXPLORATION INC.

CONDENSED CONSOLIDATED BALANCE SHEETS 

 

 

September 30,

 

 

December 31,

 

 

 

2017

 

 

2016

 

 

 

(Unaudited)

 

 

 

 

 

 

 

(in thousands, except share and per share data)

 

ASSETS

 

 

 

 

 

 

 

 

CURRENT ASSETS:

 

 

 

 

 

 

 

 

Cash and cash equivalents

 

$

29,229

 

 

$

71,529

 

Accounts receivable, net of allowance for doubtful accounts of $1,953, respectively

 

 

40,353

 

 

 

26,883

 

Commodity derivative contracts

 

 

4,400

 

 

 

6,212

 

Prepaid expenses

 

 

1,167

 

 

 

755

 

Total current assets

 

 

75,149

 

 

 

105,379

 

PROPERTY, PLANT AND EQUIPMENT:

 

 

 

 

 

 

 

 

Oil and natural gas properties, full cost method of accounting:

 

 

 

 

 

 

 

 

Unproved properties, excluded from amortization

 

 

135,945

 

 

 

67,333

 

Proved properties

 

 

1,303,165

 

 

 

1,253,061

 

Total oil and natural gas properties

 

 

1,439,110

 

 

 

1,320,394

 

Furniture and equipment

 

 

3,031

 

 

 

2,622

 

Total property, plant and equipment

 

 

1,442,141

 

 

 

1,323,016

 

Accumulated depreciation, depletion and amortization

 

 

(1,147,774

)

 

 

(1,131,012

)

Total property, plant and equipment, net

 

 

294,367

 

 

 

192,004

 

OTHER ASSETS:

 

 

 

 

 

 

 

 

Restricted cash

 

 

370

 

 

 

 

Commodity derivative contracts

 

 

416

 

 

 

1,638

 

Deferred charges, net

 

 

 

 

 

676

 

Advances to operators and other assets

 

 

100

 

 

 

102

 

Other

 

 

405

 

 

 

405

 

Total other assets

 

 

1,291

 

 

 

2,821

 

TOTAL ASSETS

 

$

370,807

 

 

$

300,204

 

LIABILITIES AND STOCKHOLDERS' DEFICIT

 

 

 

 

 

 

 

 

CURRENT LIABILITIES:

 

 

 

 

 

 

 

 

Accounts payable

 

$

11,411

 

 

$

8,867

 

Revenue payable

 

 

16,428

 

 

 

6,690

 

Accrued interest

 

 

7,271

 

 

 

3,515

 

Accrued drilling and operating costs

 

 

12,100

 

 

 

2,615

 

Advances from non-operators

 

 

1,589

 

 

 

3,504

 

Commodity derivative contracts

 

 

326

 

 

 

338

 

Commodity derivative premium payable

 

 

1,337

 

 

 

1,654

 

Asset retirement obligation

 

 

 

 

 

89

 

Other accrued liabilities

 

 

2,791

 

 

 

2,462

 

Total current liabilities

 

 

53,253

 

 

 

29,734

 

LONG-TERM LIABILITIES:

 

 

 

 

 

 

 

 

Long-term debt

 

 

333,593

 

 

 

404,493

 

Commodity derivative contracts

 

 

129

 

 

 

 

Commodity derivative premium payable

 

 

34

 

 

 

969

 

Asset retirement obligation

 

 

4,574

 

 

 

5,443

 

Total long-term liabilities

 

 

338,330

 

 

 

410,905

 

Commitments and contingencies (Note 11)

 

 

 

 

 

 

 

 

STOCKHOLDERS’ DEFICIT:

 

 

 

 

 

 

 

 

Preferred stock, par value $0.01 per share, 40,000,000 shares authorized

 

 

 

 

 

 

 

 

8.625% Series A Cumulative Preferred Stock, 10,000,000 shares designated;

   4,045,000 shares issued and outstanding at September 30, 2017 and December 31, 2016,

   respectively, with liquidation preference of $25.00 per share

 

 

41

 

 

 

41

 

10.75% Series B Cumulative Preferred Stock, 10,000,000 shares designated;

   2,140,000 shares issued and outstanding at September 30, 2017 and December 31, 2016,

   respectively, with liquidation preference of $25.00 per share

 

 

21

 

 

 

21

 

Common stock, par value $0.001 per share; 800,000,000 and 550,000,000 shares authorized at

         September 30, 2017 and December 31, 2016, respectively; 218,946,763 and

         150,377,870 shares issued and outstanding at September 30, 2017 and December 31, 2016,

         respectively

 

 

219

 

 

 

150

 

Additional paid-in capital

 

 

817,627

 

 

 

644,306

 

Accumulated deficit

 

 

(838,684

)

 

 

(784,953

)

Total stockholders’ deficit

 

 

(20,776

)

 

 

(140,435

)

TOTAL LIABILITIES AND STOCKHOLDERS’ DEFICIT

 

$

370,807

 

 

$

300,204

 

 

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

 

7


GASTAR EXPLORATION INC.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

 

 

 

For the Three Months Ended

September 30,

 

 

For the Nine Months Ended September 30,

 

 

 

2017

 

 

2016

 

 

2017

 

 

2016

 

 

 

(in thousands, except share

and per share data)

 

REVENUES:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Oil and condensate

 

$

12,952

 

 

$

10,306

 

 

$

37,886

 

 

$

30,464

 

Natural gas

 

 

2,519

 

 

 

2,500

 

 

 

7,452

 

 

 

8,394

 

NGLs

 

 

2,757

 

 

 

1,695

 

 

 

7,527

 

 

 

5,100

 

Total oil, condensate, natural gas and NGLs revenues

 

 

18,228

 

 

 

14,501

 

 

 

52,865

 

 

 

43,958

 

(Loss) gain on commodity derivatives contracts

 

 

(2,896

)

 

 

(1,498

)

 

 

3,782

 

 

 

(3,991

)

Total revenues

 

 

15,332

 

 

 

13,003

 

 

 

56,647

 

 

 

39,967

 

EXPENSES (BENEFIT):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Production taxes

 

 

721

 

 

 

400

 

 

 

1,675

 

 

 

1,469

 

Lease operating expenses

 

 

6,178

 

 

 

5,166

 

 

 

16,396

 

 

 

15,829

 

Transportation, treating and gathering

 

 

436

 

 

 

338

 

 

 

1,187

 

 

 

1,346

 

Depreciation, depletion and amortization

 

 

6,059

 

 

 

5,223

 

 

 

16,762

 

 

 

24,543

 

Impairment of oil and natural gas properties

 

 

 

 

 

 

 

 

 

 

 

48,497

 

Accretion of asset retirement obligation

 

 

62

 

 

 

92

 

 

 

171

 

 

 

286

 

General and administrative expense

 

 

4,067

 

 

 

3,925

 

 

 

12,482

 

 

 

15,872

 

Litigation settlement benefit

 

 

 

 

 

(10,100

)

 

 

 

 

 

(10,100

)

Total expenses

 

 

17,523

 

 

 

5,044

 

 

 

48,673

 

 

 

97,742

 

(LOSS) INCOME FROM OPERATIONS

 

 

(2,191

)

 

 

7,959

 

 

 

7,974

 

 

 

(57,775

)

OTHER INCOME (EXPENSE):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Interest expense

 

 

(10,159

)

 

 

(8,178

)

 

 

(29,744

)

 

 

(26,739

)

Loss on early extinguishment of debt

 

 

 

 

 

 

 

 

(12,172

)

 

 

 

Investment income and other (expense)

 

 

51

 

 

 

41

 

 

 

166

 

 

 

(2

)

LOSS BEFORE PROVISION FOR INCOME TAXES

 

 

(12,299

)

 

 

(178

)

 

 

(33,776

)

 

 

(84,516

)

Provision for income taxes

 

 

 

 

 

 

 

 

 

 

 

 

NET LOSS

 

 

(12,299

)

 

 

(178

)

 

 

(33,776

)

 

 

(84,516

)

Dividends on preferred stock

 

 

(1,206

)

 

 

 

 

 

(8,443

)

 

 

(3,618

)

Undeclared cumulative dividends on preferred stock

 

 

(2,412

)

 

 

(3,618

)

 

 

(2,412

)

 

 

(7,237

)

NET LOSS ATTRIBUTABLE TO COMMON

   STOCKHOLDERS

 

$

(15,917

)

 

$

(3,796

)

 

$

(44,631

)

 

$

(95,371

)

NET LOSS PER SHARE OF COMMON STOCK ATTRIBUTABLE TO COMMON STOCKHOLDERS:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Basic

 

$

(0.08

)

 

$

(0.03

)

 

$

(0.23

)

 

$

(0.92

)

Diluted

 

$

(0.08

)

 

$

(0.03

)

 

$

(0.23

)

 

$

(0.92

)

WEIGHTED AVERAGE SHARES OF COMMON STOCK

   OUTSTANDING:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Basic

 

 

209,072,232

 

 

 

129,301,817

 

 

 

190,745,688

 

 

 

104,125,317

 

Diluted

 

 

209,072,232

 

 

 

129,301,817

 

 

 

190,745,688

 

 

 

104,125,317

 

 

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

 

 

 

8


GASTAR EXPLORATION INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

 

 

 

For the Nine Months Ended

September 30,

 

 

 

2017

 

 

2016

 

 

 

(in thousands)

 

CASH FLOWS FROM OPERATING ACTIVITIES:

 

 

 

 

 

 

 

 

Net loss

 

$

(33,776

)

 

$

(84,516

)

Adjustments to reconcile net loss to net cash provided by

   operating activities:

 

 

 

 

 

 

 

 

Depreciation, depletion and amortization

 

 

16,762

 

 

 

24,543

 

Impairment of oil and natural gas properties

 

 

 

 

 

48,497

 

Stock-based compensation

 

 

3,990

 

 

 

3,145

 

Mark to market of commodity derivatives contracts:

 

 

 

 

 

 

 

 

Total (gain) loss on commodity derivatives contracts

 

 

(3,782

)

 

 

3,991

 

Cash settlements of matured commodity derivatives contracts, net

 

 

5,602

 

 

 

10,690

 

Cash premiums paid for commodity derivatives contracts

 

 

 

 

 

(565

)

Amortization of deferred financing costs and debt discount

 

 

8,218

 

 

 

3,812

 

Accretion of asset retirement obligation

 

 

171

 

 

 

286

 

Settlement of asset retirement obligation

 

 

 

 

 

(87

)

Loss on sale of furniture and equipment

 

 

 

 

 

97

 

Loss on early extinguishment of debt

 

 

12,172

 

 

 

 

Changes in operating assets and liabilities:

 

 

 

 

 

 

 

 

Accounts receivable

 

 

(13,466

)

 

 

3,861

 

Prepaid expenses

 

 

(412

)

 

 

362

 

Accounts payable and accrued liabilities

 

 

13,657

 

 

 

7,656

 

Net cash provided by operating activities

 

 

9,136

 

 

 

21,772

 

CASH FLOWS FROM INVESTING ACTIVITIES:

 

 

 

 

 

 

 

 

Development and purchase of oil and natural gas properties

 

 

(81,906

)

 

 

(43,175

)

(Acquisition of) refund for oil and natural gas properties

 

 

(54,462

)

 

 

1,149

 

Proceeds from sale of oil and natural gas properties

 

 

28,798

 

 

 

77,499

 

Application of proceeds from non-operators

 

 

(1,915

)

 

 

(57

)

(Advances to) reimbursements from operators

 

 

(22

)

 

 

211

 

(Purchase) sale of furniture and equipment

 

 

(409

)

 

 

80

 

Net cash (used in) provided by investing activities

 

 

(109,916

)

 

 

35,707

 

CASH FLOWS FROM FINANCING ACTIVITIES:

 

 

 

 

 

 

 

 

Proceeds from term loan

 

 

250,000

 

 

 

 

Proceeds from convertible notes

 

 

200,000

 

 

 

 

Repayment of senior secured notes

 

 

(325,000

)

 

 

 

Repayment of revolving credit facility

 

 

(84,630

)

 

 

(100,370

)

Loss on early extinguishment of debt

 

 

(7,011

)

 

 

 

Proceeds from issuance of common stock, net of issuance costs

 

 

56,366

 

 

 

44,815

 

Dividends on preferred stock

 

 

(19,298

)

 

 

(3,618

)

Deferred financing charges

 

 

(10,991

)

 

 

(930

)

Increase in restricted cash

 

 

(370

)

 

 

 

Tax withholding related to restricted stock and performance based unit award vestings

 

 

(586

)

 

 

(711

)

Net cash provided by (used in) financing activities

 

 

58,480

 

 

 

(60,814

)

NET DECREASE IN CASH AND CASH EQUIVALENTS

 

 

(42,300

)

 

 

(3,335

)

CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD

 

 

71,529

 

 

 

50,074

 

CASH AND CASH EQUIVALENTS, END OF PERIOD

 

$

29,229

 

 

$

46,739

 

 

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

 

 

 

9


GASTAR EXPLORATION INC.

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

 

 

1.

Description of Business

Gastar Exploration Inc. (the “Company” or “Gastar”) is a pure play Mid-Continent independent energy company engaged in the exploration, development and production of oil, condensate, natural gas and NGLs. Gastar’s principal business activities include the identification, acquisition, and subsequent exploration and development of oil and natural gas properties with an emphasis on unconventional reserves, such as shale resource plays. Gastar holds a concentrated acreage position in the normally pressured oil window of the STACK Play, an area of central Oklahoma which is home to multiple oil and natural gas-rich reservoirs including the Oswego limestone, Meramec and Osage bench formations within the Mississippi Lime, the Woodford shale and Hunton limestone formations.    

 

 

2.

Summary of Significant Accounting Policies

The accounting policies followed by the Company are set forth in the notes to the Company’s audited consolidated financial statements included in its Annual Report on Form 10-K for the year ended December 31, 2016 (the “2016 Form 10-K”) filed with the SEC. Please refer to the notes to the consolidated financial statements included in the 2016 Form 10-K for additional details of the Company’s financial condition, results of operations and cash flows. No material item included in those notes has changed except as a result of normal transactions in the interim or as disclosed within this report.

The unaudited interim condensed consolidated financial statements of the Company included herein are stated in U.S. dollars and were prepared from the records of the Company by management in accordance with U.S. GAAP applicable to interim financial statements and reflect all normal and recurring adjustments, which are, in the opinion of management, necessary to provide a fair presentation of the results of operations and financial position for the interim periods. Such financial statements conform to the presentation reflected in the 2016 Form 10-K. The current interim period reported herein should be read in conjunction with the financial statements and accompanying notes, including Item 8. “Financial Statements and Supplementary Data, Note 2 – Summary of Significant Accounting Policies,” included in the 2016 Form 10-K.

The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Significant estimates with regard to these financial statements include the valuation of convertible debt, estimate of proved oil and natural gas reserve quantities and the related present value of estimated future net cash flows.

The unaudited interim condensed consolidated financial statements of the Company include the consolidated accounts of all of its subsidiaries. All significant intercompany accounts and transactions have been eliminated in consolidation.

The results of operations for the three and nine months ended September 30, 2017 are not necessarily indicative of the results that may be expected for the year ending December 31, 2017.

Subsequent Events

In preparing these financial statements, the Company has evaluated events and transactions for potential recognition or disclosure through the date the financial statements were issued and has disclosed certain subsequent events in these condensed consolidated financial statements, as appropriate.

 

Accounts Receivable

Accounts receivable are reported net of the allowance for doubtful accounts.  The allowance for doubtful accounts is determined based on a review of the Company’s receivables.  Receivable accounts are charged off when collection efforts have failed or the account is deemed uncollectible.  During 2016, the Company determined that a receivable account from a third-party natural gas and NGLs purchaser would no longer be collectible as a result of the third-party purchaser filing for bankruptcy.  A summary of the activity related to the allowance for doubtful accounts is as follows:

 

 

10


 

 

September 30,

2017

 

 

December 31,

2016

 

 

 

(in thousands)

 

Allowance for doubtful accounts, beginning of period

 

$

1,953

 

 

$

 

Expense

 

 

 

 

 

1,953

 

Reductions/write-offs

 

 

 

 

 

 

Allowance for doubtful accounts, end of period

 

$

1,953

 

 

$

1,953

 

Recent Accounting Developments

Business Combinations.  In January 2017, the FASB issued updated guidance to clarify the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses.  The amendments in this update provide a screen to determine when a set is not a business.  The screen requires that when substantially all of the fair value of the gross assets acquired (or disposed of) is concentrated in a single identifiable asset or a group of similar identifiable assets, the set is not a business.  This screen reduces the number of transactions that need to be further evaluated.  If the screen is not met, the amendments in this update (1) require that to be considered a business, a set must include, at a minimum, an input and a substantive process that together significantly contribute to the ability to create output and (2) remove the evaluation of whether a market participant could replace missing elements.  The amendments in this update affect all reporting entities that must determine whether they have acquired or sold a business and are effective for public business entities for annual reporting periods beginning after December 15, 2017, including interim periods within those periods.  The amendments should be applied prospectively on or after the effective date and no disclosures are required at transition.  Early application is allowed as follows (1) for transactions for which the acquisition date occurs before the issuance date or effective date of the amendments, only when the transaction has not been reported in financial statements that have been issued or made available for issuance and (2) for transactions in which a subsidiary is deconsolidated or a group of assets is derecognized that occur before the issuance date or effective date of the amendments, only when the transaction has not been reported in financial statements that have been issued or made available for issuance.  The application of this guidance to future acquisitions and disposals could have an effect on the Company’s financial position or results of operations.

Statement of Cash Flows. In August 2016, the FASB issued updated guidance associated with the classification of certain cash receipts and cash payments on the statement of cash flows. The amended guidance addresses specific cash flow issues with the objective of reducing existing diversity in practice.  The amendment provides guidance on the following eight specific cash flow issues: debt prepayment or debt extinguishment costs; settlement of zero-coupon debt instruments or other debt instruments with coupon interest rates that are insignificant in relation to the effective interest rate of the borrowing; contingent consideration payments made after a business combination; proceeds from the settlement of insurance claims; proceeds from the settlement of corporate-owned life insurance policies; distributions received from equity method investees; beneficial interests in securitization transactions; and separately identifiable cash flows and application of the predominance principle.  The amendments in this update apply to all entities required to present a statement of cash flows.  The amendments in this update are effective for public business entities for fiscal years beginning after December 15, 2017 and interim periods within those fiscal years.  Early adoption is permitted, including adoption in an interim period.  If an entity early adopts the amendments in an interim period, any adjustments should be reflected as of the beginning of the fiscal year that includes that interim period.  An entity that elects early adoption must adopt all of the amendments in the same period.  Amendments should be applied using a retrospective transition method to each period presented.  If it is impracticable to apply the amendments retrospectively for some of the issues, the amendments for those issues would be applied prospectively as of the earliest date practicable.  The Company is currently evaluating the effect that adopting this guidance will have on its presentation of cash flows and does not believe the effects of adopting this updated guidance will have a material effect on its statement of cash flows nor that it will affect the Company’s financial position or results of operations.    

Compensation – Stock Compensation.  In March 2016, the FASB issued updated guidance as part of its simplification initiative which is intended to simplify several aspects of the accounting for stock-based compensation transactions, including the income tax consequences, classification of awards as either equity or liabilities and classification on the statement of cash flows.  For public business entities, the amendments in this update are effective for annual periods beginning after December 15, 2016, and interim periods within those annual periods.  Amendments related to the timing of when excess tax benefits are recognized, minimum statutory withholding requirements, forfeitures, and intrinsic value should be applied using a modified retrospective transition method by means of a cumulative-effect adjustment to equity as of the beginning of the period in which the guidance is adopted.  Amendments related to the presentation of employee taxes paid on the statement of cash flows when an employer withholds shares to meet the minimum statutory withholding requirement should be applied retrospectively.  Amendments requiring recognition of excess tax benefits and tax deficiencies in the income statement and the practical expedient for estimating expected term should be applied prospectively.  An entity may elect to apply the amendments related to the presentation of excess tax benefits on the statement of cash flows using either a prospective transition method or a retrospective transition method. The Company adopted this updated guidance for the fiscal year beginning January 1, 2017 and recorded a cumulative adjustment of approximately $657,000 to retained earnings to properly reflect the adjustment to stock compensation expense to reduce the forfeiture rate to 0%.

 

11


Leases.  In February 2016, the FASB issued updated guidance to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and enhance disclosures regarding key information about leasing arrangements.  Under the new guidance, lessees will be required to recognize a lease liability and a right-of-use asset for all leases. The new lease guidance also simplified the accounting for sale and leaseback transactions primarily because lessees must recognize lease assets and lease liabilities. The amendments in this update are effective beginning on January 1, 2019 and should be applied through a modified retrospective transition approach for leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements.  Early adoption is permitted.  The Company has begun analyzing its lease contracts but has not yet determined what the effects of adopting this updated guidance will be on its consolidated financial statements.

Income Taxes.  In November 2015, the FASB issued updated guidance as part of its simplification initiative for the presentation of deferred taxes.  Current U.S. GAAP requires an entity to separate deferred income tax liabilities and assets into current and noncurrent amounts in a classified statement of financial position where such classification generally does not align with the time period in which the recognized deferred tax amounts are expected to be recovered or settled.  To simplify the presentation of deferred income taxes, the amendments in this update require that deferred tax liabilities and assets be classified as noncurrent in a classified statement of financial position and apply to all entities that present a classified statement of financial position, resulting in the alignment of the presentation of deferred income tax assets and liabilities with International Financial Reporting Standards. International Accounting Standard 1, Presentation of Financial Statements.  This updated guidance is effective for public business entities for financial statements issued for annual periods beginning after December 15, 2016, and interim periods within those annual periods.  The Company has adopted this guidance prospectively and such adoption did not have an impact on its consolidated financial statements.

Revenue Recognition.  In May 2014, the FASB issued an amendment to previously issued guidance regarding the recognition of revenue, which supersedes the revenue recognition requirements in Accounting Standards Codification Topic 605, “Revenue Recognition,” and most industry-specific guidance.  The FASB and the International Accounting Standards Board initiated a joint project to clarify the principles for recognizing revenue and to develop a common standard that would (i) remove inconsistencies and weaknesses in revenue requirements, (ii) provide a more robust framework for addressing revenue issues, (iii) improve comparability of revenue recognition practices across entities, industries, jurisdictions and capital markets, (iv) provide more useful information to users of financial statements through improved disclosure requirements and (v) simplify the preparation of financial statements by reducing the number of requirements to which an entity must refer.  The core principle of the guidance is that an entity 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.  To achieve this core principle, an entity should apply the following steps: (1) identify the contract(s) with the customer; (2) identify the performance obligations in the contract; (3) determine the transaction price; (4) allocate the transaction price to the performance obligations in the contract; and (5) recognize revenue when (or as) the entity satisfies a performance obligation.  This guidance supersedes prior revenue recognition requirements and most industry-specific guidance throughout the FASB Accounting Standards Codification.   In 2015, the FASB delayed the effective date one year, beginning in fiscal year 2018.  

The Company has substantially completed its scoping and assessment of impact of the new revenue recognition standard.

The Company has evaluated a representative sample of revenue contracts related to its oil, natural gas and NGLs revenues.  For these contracts, the Company has reviewed the contract provisions and evaluated the contracts under the new standard to assess the impact on the quantum and timing of revenue recognition and presentation of revenues on adoption of the new guidance.  The Company believes that it has identified all material contract types and contractual features that represent the Company’s revenue.  Based upon work completed to date, the Company does not currently expect that the adoption of this standard will have a material impact on net profit, although the Company does believe that certain reclassifications between revenue and expenses may be required based upon its assessment of i) where control passes to the customer and ii) whether the Company represents the principal or agent in certain arrangements.  In addition, the Company’s disclosures surrounding revenue recognition will be more substantial upon adoption.  These conclusions are subject to change and the Company is continuing to evaluate the requirements of this standard as it works towards finalizing its assessment, and as it continues to perform other implementation activities such as establishing new policies, procedures and controls, quantifying the adoption date adjustments and drafting disclosures.  The Company is required to apply this new standard beginning January 1, 2018.  Two methods of transition are permitted under this standard: the full retrospective method, in which the standard would be applied retrospectively to each prior reporting period presented, subject to certain allowable exceptions; or the modified retrospective method, in which the standard would be applied to all contracts existing as of the date of initial application, with the cumulative effect of applying the standard recognized in retained earnings (the adoption date adjustments).  The Company anticipates adopting this standard using the modified retrospective method.

 

 

3.

Property, Plant and Equipment

The amount capitalized as oil and natural gas properties was incurred for the purchase and development of various properties in the U.S., specifically the states of Oklahoma, Pennsylvania and West Virginia.  On April 8, 2016, the Company sold substantially all

 

12


of its producing assets and proved reserves and a significant portion of its undeveloped acreage in Pennsylvania and West Virginia comprising the Company’s assets in the Appalachian Basin.  On January 20, 2017, the Company sold its remaining interest in producing wells and undeveloped acreage in West Virginia, effective January 1, 2017, for $200,000 before fees and expenses.

The following table summarizes the components of unproved properties excluded from amortization at the dates indicated:

 

 

 

September 30,

2017

 

 

December 31,

2016

 

 

 

(in thousands)

 

Unproved properties, excluded from amortization:

 

 

 

 

 

 

 

 

Drilling in progress costs

 

$

10,881

 

 

$

1,100

 

Acreage acquisition costs

 

 

113,110

 

 

 

58,857

 

Capitalized interest

 

 

11,954

 

 

 

7,376

 

Total unproved properties excluded from amortization

 

$

135,945

 

 

$

67,333

 

 

The full cost method of accounting for oil and natural gas properties requires a quarterly calculation of a limitation on capitalized costs, often referred to as a full cost ceiling calculation. The ceiling is the present value (discounted at 10% per annum) of estimated future cash flow from proved oil, condensate, natural gas and NGLs reserves reduced by future operating expenses, development expenditures, abandonment costs (net of salvage) to the extent not included in oil and natural gas properties pursuant to authoritative guidance and estimated future income taxes thereon. To the extent that the Company's capitalized costs (net of accumulated depletion and deferred taxes) exceed the ceiling at the end of each reporting period, the excess must be written off to expense for such period. Once incurred, this impairment of oil and natural gas properties is not reversible at a later date even if oil and natural gas prices increase. The ceiling calculation is determined using a mandatory trailing 12-month unweighted arithmetic average of the first-day-of-the-month commodities pricing and costs in effect at the end of the period, each of which are held constant indefinitely (absent specific contracts with respect to future prices and costs) with respect to valuing future net cash flows from proved reserves for this purpose.  The 12-month unweighted arithmetic average of the first-day-of-the-month commodities prices are adjusted for basis and quality differentials in determining the present value of the proved reserves.  The table below sets forth relevant pricing assumptions utilized in the quarterly ceiling test computations for the respective periods noted before adjustment for basis and quality differentials:

 

 

 

2017

 

 

 

Total Year to Date

Impairment

 

 

September 30

 

 

June 30

 

 

March 31

 

Henry Hub natural gas price (per MMBtu)(1)

 

 

 

 

 

$

3.00

 

 

$

3.01

 

 

$

2.73

 

WTI oil price (per Bbl)(1)

 

 

 

 

 

$

49.81

 

 

$

48.95

 

 

$

47.61

 

Impairment recorded (pre-tax) (in thousands)

 

$

 

 

$

 

 

$

 

 

$

 

 

 

 

2016

 

 

 

Total Year to Date

Impairment

 

 

September 30

 

 

June 30

 

 

March 31

 

Henry Hub natural gas price (per MMBtu)(1)

 

 

 

 

 

$

2.28

 

 

$

2.24

 

 

$

2.40

 

WTI oil price (per Bbl)(1)

 

 

 

 

 

$

41.68

 

 

$

43.12

 

 

$

46.26

 

Impairment recorded (pre-tax) (in thousands)

 

$

48,497

 

 

$

 

 

$

 

 

$

48,497

 

 

(1)

For the respective periods, oil and natural gas prices are calculated using the trailing 12-month unweighted arithmetic average of the first-day-of-the-month prices based on Henry Hub spot natural gas prices and WTI spot oil prices.

The Company could potentially incur ceiling test impairments in the future should commodities prices decline. However, it is difficult to project future impairment charges in light of numerous variables involved.

The Company’s proved reserves estimates and their estimated discounted value and standardized measure will also be impacted by changes in lease operating costs, future development costs, production, exploration and development activities and estimated future income taxes.  The ceiling limitation calculation is not intended to be indicative of the fair market value of the Company’s proved reserves or future results.

STACK Leasehold Acquisition

On March 22, 2017, the Company completed the acquisition of additional working and net revenue interests in approximately 66 gross (9.5 net) producing wells and 5,670 net acres of additional undeveloped STACK Play leasehold in Kingfisher County,

 

13


Oklahoma, effective March 1, 2017, for $51.4 million (the “STACK Leasehold Acquisition”).  Prior to the completion of the STACK Leasehold Acquisition, the Company held an interest in the majority of acquired producing wells and acreage.  The Company accounted for the STACK Leasehold Acquisition as an asset acquisition.  

Development Agreement

On October 14, 2016, the Company executed an agreement with STACK Exploration LLC (the “Investor”) (the “Development Agreement”) to jointly develop up to 60 Gastar operated wells in the STACK Play in Kingfisher County, Oklahoma (the “Drilling Program”).  The Drilling Program targeted the Meramec and Osage formations within the Mississippi Lime in a contract area within three townships covering approximately 32,900 gross (21,200 net) undeveloped mineral acres under leases held by the Company. The Company is the operator of all wells jointly developed under the Development Agreement.      

Under the Development Agreement, the Investor funded 90% of the Company’s working interest portion of drilling and completion costs to initially earn 80% of the Company’s working interest in each new well (in each case, proportionately reduced by other participating working interests in the well).  As a result, the Company paid 10% of its working interest portion of such costs for 20% of its original working interest.  

The proposed Drilling Program wells were to be mutually developed in three tranches of 20 wells each.  The locations of the first 20 wells, comprised of 18 Meramec formation wells and two Osage formation wells, were mutually agreed upon by the Company and the Investor.   Participation in the second tranche of 20 Drilling Program wells was to be at the election of the Investor and the third tranche of 20 wells would require mutual consent.  On July 31, 2017, the Investor elected not to participate in the second tranche of wells.  With respect to each 20-well tranche, when the Investor has achieved an aggregate 15% internal rate of return for its investment in the tranche, Investor’s interest will be reduced from 80% to 40% of the Company’s original working interest and the Company’s working interest increases from 20% to 60% of its original working interest.  When a tranche internal rate of return of 20% is achieved by the Investor, Investor’s working interest decreases to 10% and the Company’s working interest increases to 90% of the working interest originally owned by the Company.  

Upon completion of a tranche, the Investor has the right, but not the obligation, for a period of six months to cause the Company to purchase the Investor’s interest in the Drilling Program t