Press Release

Press Release

Aug 9, 2018
Gastar Exploration Announces Second Quarter 2018 Results

HOUSTON, Aug. 9, 2018 /PRNewswire/ -- Gastar Exploration Inc. (NYSE American: GST) ("Gastar" or the "Company") today reported financial and operating results for the three and six months ended June 30, 2018. 

Net loss attributable to Gastar's common stockholders for the second quarter of 2018 was $39.4 million, or a loss of $0.19 per share, compared to a second quarter 2017 net loss of $6.4 million, or a loss of $0.03 per share.  Adjusted net loss attributable to common stockholders for the second quarter of 2018 was $15.3 million, or a loss of $0.07 per share, excluding the impact of an $18.0 million non-cash, pre-tax ceiling test impairment charge and a $6.1 million loss resulting from the mark-to-market of outstanding hedge positions compared to an adjusted net loss of $9.8 million, or a loss of $0.05 per share, for the second quarter of 2017 which excludes $3.4 million of gains resulting from the mark-to-market of outstanding hedge positions. The increase in the adjusted net loss is due to the sale of the Company's West Edmund Hunton Lime Unit ("WEHLU") assets in February 2018 coupled with increased interest and depreciation, depletion and amortization  expense.  (See the accompanying reconciliation of the non-GAAP financial measure adjusted net loss at the end of this news release.)

Adjusted earnings before interest, income taxes, depreciation, depletion and amortization ("adjusted EBITDA") (non-GAAP) for the second quarter of 2018 decreased 26% to $7.3 million compared to $9.8 million for the second quarter of 2017 and decreased 40% sequentially from $12.0 million for the first quarter of 2018. The sequential decline in adjusted EBITDA was primarily due to the sale of the Company's WEHLU assets.  (See the accompanying reconciliation of the non-GAAP financial adjusted EBITDA at the end of this news release.)

Revenues from oil, condensate, natural gas and natural gas liquids ("NGLs"), before the effects of commodity derivatives contracts, totaled $19.5 million in the second quarter of 2018, a 13% increase from $17.3 million in the second quarter of 2017 and a 26% decrease from $26.4 million in the first quarter of 2018.  The increase from the second quarter of 2017 in oil, condensate, natural gas and NGLs revenues primarily resulted from a 21% increase in equivalent product pricing, partially offset by a 7% decrease in equivalent production volumes primarily due to the sale of the Company's WEHLU assets.  The decrease from first quarter 2018 revenues was due to a 6% decrease in equivalent product pricing and a 22% decrease in equivalent production volumes due to the sale of the WEHLU assets.  Second quarter 2018 oil, condensate, natural gas and NGLs revenues were net of transportation, treating and gathering costs of $1.2 million pursuant to current authoritative accounting guidance. 

Commodity derivative contracts settled during the second quarter of 2018 resulted in a $3.1 million decrease in revenue compared to a $2.0 million increase in revenues in the second quarter of 2017.  For details on Gastar's current hedging position, please see our Quarterly Report on Form 10-Q for the quarter ended June 30, 2018 filed today with the United States Securities and Exchange Commission (the "SEC").

The following table provides a summary of Gastar's total net production volumes and overall average commodity prices for the three and six months ended June 30, 2018 and 2017:  

 

For the Three Months Ended

June 30,

 

For the Six Months Ended

June 30,

 

2018

 

2017

 

2018

 

2017

               

Net Production:

                     

Oil and condensate (MBbl)

 

241

   

277

   

583

   

527

Natural gas (MMcf)

 

1,075

   

923

   

2,138

   

1,785

NGLs (MBbl)

 

99

   

128

   

243

   

245

Total net production (MBoe)

 

519

   

559

   

1,183

   

1,070

Net Daily production:

                     

Oil and condensate (MBbl/d)

 

2.6

   

3.0

   

3.2

   

2.9

Natural gas (MMcf/d)

 

11.8

   

10.1

   

11.8

   

9.9

NGLs (MBbl/d)

 

1.1

   

1.4

   

1.3

   

1.4

Total net daily production (MBoe/d)

 

5.7

   

6.1

   

6.5

   

5.9

Average sales price per unit(1):

                     

Oil and condensate per Bbl, including impact of hedging activities (2)

$

55.44

 

$

52.21

 

$

55.31

 

$

53.31

Oil and condensate per Bbl, excluding impact of hedging activities

$

66.80

 

$

45.94

 

$

63.52

 

$

47.28

Natural gas per Mcf, including impact of hedging activities (2)

$

1.44

 

$

2.51

 

$

1.84

 

$

2.85

Natural gas per Mcf, excluding impact of hedging activities

$

1.35

 

$

2.54

 

$

1.70

 

$

2.76

NGLs per Bbl, including impact of hedging activities (2)

$

14.73

 

$

19.41

 

$

18.01

 

$

21.74

NGLs per Bbl, excluding impact of hedging activities

$

19.58

 

$

17.02

 

$

21.48

 

$

19.45

Average sales price per Boe, including impact of hedging activities(1)(2)

$

31.49

 

$

34.49

 

$

34.32

 

$

36.02

Average sales price per Boe, excluding impact of hedging activities(1)

$

37.51

 

$

30.88

 

$

38.82

 

$

32.37

                       

Lease operating expense per Boe

$

9.19

 

$

9.20

 

$

10.38

 

$

9.55

_____________________________

(1)

Average sales price per unit for 2018 are net of transportation, treating and gathering costs, which were previously reported separately as expenses. 

(2)

The impact of hedging includes only the gain (loss) on commodity derivative contracts settled during the periods presented.

The following table provides a summary of Gastar's Mid-Continent STACK Play production volumes and average commodity prices, excluding the sale of our WEHLU assets, for the three and six months ended June 30, 2018 and 2017:

 

For the Three Months Ended

June 30,

 

For the Six Months Ended

June 30,

 

2018

 

2017

 

2018

 

2017

STACK Play (excludes WEHLU)

                     

Net Production:

                     

Oil and condensate (MBbl)

 

241

   

125

   

502

   

224

Natural gas (MMcf)

 

1,075

   

489

   

1,894

   

923

NGLs (MBbl)

 

99

   

54

   

195

   

101

Total net production (MBoe)

 

519

   

260

   

1,013

   

479

Net Daily Production:

                     

Oil and condensate (MBbl/d)

 

2.6

   

1.4

   

2.8

   

1.2

Natural gas (MMcf/d)

 

11.8

   

5.4

   

10.5

   

5.1

NGLs (MBbl/d)

 

1.1

   

0.6

   

1.1

   

0.6

Total net daily production (MBoe/d)

 

5.7

   

2.9

   

5.6

   

2.6

Average sales price per unit(1):

                     

Oil and condensate (per Bbl)

$

66.81

 

$

46.24

 

$

63.90

 

$

47.36

Natural gas (per Mcf)

$

1.35

 

$

2.76

 

$

1.58

 

$

2.88

NGLs (per Bbl)

$

19.58

 

$

18.32

 

$

21.04

 

$

20.76

Average sales price per Boe(1)

$

37.51

 

$

31.15

 

$

38.68

 

$

32.09

                       

Lease operating expense per Boe

$

9.19

 

$

9.70

 

$

9.97

 

$

9.76

_____________________________

(1)

Excludes the impact of hedging activities.  Average sales price per unit for 2018 are net of transportation, treating and gathering costs, which were previously reported separately as expenses

STACK Play production for the second quarter of 2018 consisted of approximately 66% liquids, (comprised of 46% oil and 20% NGLs), down from 72% and 69% liquids in the first quarter of 2018 and second quarter of 2017, respectively.  The percentage of liquids as a component of production in the second quarter of 2018 was down sequentially due to certain new wells brought online during the second quarter of 2018 producing significantly higher volumes of natural gas.

General and administrative ("G&A") expense was $4.9 million in the second quarter of 2018 compared to $4.6 million in the second quarter of 2017 and $9.0 million in the first quarter of 2018. The decrease in second quarter 2018 G&A expense compared to first quarter 2018 was primarily due to severance costs incurred during the first quarter of 2018.  G&A expense for the second quarter of 2018 included $1.2 million of non-cash stock-based compensation expense, versus $1.2 million in the second quarter of 2017 and $1.7 million in the first quarter of 2018.  Excluding non-cash stock based compensation, cash G&A expense per Boe for the second quarters of 2018 and 2017 and the first quarter of 2018, excluding severance costs, were $7.10, $6.06 and $5.57, respectively.

During the second quarter of 2018, Gastar recorded an impairment of oil and natural gas properties of approximately $18.0 million due to the downward revision of its proved reserve quantities. The downward revision was primarily associated with the decision to reclassify proved undeveloped reserves to unproved reserves due to the uncertainty regarding the timing and availability of funding required to develop these reserves. 

Exploration of Strategic Alternatives

As previously reported, the Company's management and Board of Directors (the "Board") are working closely with the Company's financial and legal advisors to consider potential strategic transactions, including financing alternatives and sale or merger transactions and is encouraging proposals from existing stakeholders and interested third-parties.  The Company has formed a special committee consisting of directors not affiliated with Ares (defined below), including Jerry Schuyler, Gastar's Interim Chief Executive Officer and Board Chairman, and Board members Randolph Coley and Harry Quarls, who, along with the advisors, are exploring a wide range of strategic alternatives for the Company's future, including a sale, business combination or strategic merger and/or restructuring of its balance sheet.

On July 20, 2018, the Company received a non-binding preliminary term sheet from funds affiliated with Ares Management LLC ("Ares") proposing a potential restructuring transaction through a sale or a court-approved bankruptcy sale process or a Chapter 11 plan of reorganization.  The Company continues to review and evaluate the Ares proposal, and is open to and will similarly evaluate any other proposals from other stakeholders or third-parties. Additionally, the Company intends to distribute a process letter to prospective bidders and investors in the coming weeks that provides additional details regarding the Company's financial restructuring process, including key deadlines.  The process letter and other information related to the Company's financial restructuring process will be available on the Company's Investor Relations website at https://ir.gastar.com/investor-relations.  

Mr. Schuyler added, "Through this process, our Board is committed to evaluating strategic alternatives in an effort to maximize value for our stakeholders while simultaneously supporting the Company's management and employees."

The Company may not comment further regarding this process unless a specific transaction or other alternative is approved by the Board, this process is concluded or it is otherwise determined that further disclosure is appropriate or required by law.  The Company cannot assure you that it will be able to achieve a transaction on favorable terms or at all. 

Operations Review and Update

During the second quarter of 2018, through its one-rig drilling program, Gastar spud four gross (3.7 net) operated Osage wells and two gross (1.9 net) operated Meramec wells and completed five gross (4.9 net) Osage operated wells using its new 35-stage completion design.  The Company also participated in numerous third-party wells across its highly contiguous, 69,400 net acre STACK Play acreage position.  This position is approximately 84% operated and 73% held by production. 

The Company recently elected to suspend its operated drilling program and release the rig to allow time to fully analyze results of its 35-stage completion design as well as preserve capital for other cash needs, including but not limited to debt service while all strategic alternatives are considered or a possible restructuring of its debt and equity.  The Company intends to continue to participate in select non-operated wells and renew certain leases to preserve its STACK Play acreage position.  The Company believes it needs to consummate a substantial financing, refinancing or other financial restructuring transaction in the relative near term to re-engage in normal operated drilling activities. 

Capital Budget

Gastar's capital expenditures in the second quarter of 2018 totaled $42.0 million, comprised of $32.8 million for drilling, completions and infrastructure costs, $6.0 million for unproved acreage extensions, renewals and additions and $3.2 million for other capitalized costs resulting in year-to-date total capital expenditures of $76.8 million.  With the suspension of the operated drilling program in August 2018 and anticipated completion of five operated wells, capital expenditures for the remainder of 2018 are estimated to total $45.3 million, comprised of $34.2 million for drilling, completions and infrastructure costs, $6.2 million for unproved acreage extensions, renewals and additions and $4.9 million for other capitalized costs.  It is unlikely that the Company could materially reduce capital expenditures further without creating the risk for deterioration of the Company's core business. 

Guidance for Third Quarter 2018 and Full-Year 2018

Our guidance for the third quarter and full-year 2018, excluding WEHLU results, is presented in the table below and represents the Company's best estimate of the range of likely future results. Guidance could be affected by the factors described below in "Forward Looking Statements."

Production

 

Third Quarter

2018

 

Full-Year 2018

 
           

Net average daily (MBoe/d)(1)

 

5.2 – 5.6

 

5.5 – 5.8

 

Liquids percentage

 

66% – 70%

 

67% – 70%

 
           

Cash Operating Expenses

         

Production taxes (% of production revenues)

 

5.3% – 5.8%

 

4.3% – 4.8%

 

Direct lease operating ($/Boe)

 

$9.20 – $9.70

 

$9.00 – $9.60

 

Cash general & administrative ($/Boe)(2)

 

$5.30 – $5.70

 

$5.90 – $6.40

 

________________

(1)

Based on equivalent of 6 thousand cubic feet (Mcf) of natural gas to one barrel of oil, condensate or NGLs.

(2)

Excludes costs associated with the strategic alternatives process.

Mid-Year 2018 Reserve Update

SEC proved reserve estimates as of June 30, 2018 totaled 10.5 MMBoe, a 76% decrease over year-end 2017 proved reserves, primarily due to the sale of 19.8 MMBoe of proved reserves associated with the Company's WEHLU assets in February 2018 and the reclassification of approximately 14.8 MMBoe of proved undeveloped reserves to unproved reserves due to the uncertainty regarding the timing and availability of funding required to develop these reserves.  The proved undeveloped reserves that were reclassified to unproved remain economically producible at current commodities prices, and the Company may report proved undeveloped reserves in the future if it determines that it has the financial capability to execute a development plan.  The mid-year 2018 reserves were 93% proved developed and comprised of 4.2 million barrels of crude oil and condensate, 2.6 million barrels of NGLs and 22.1 billion cubic feet of natural gas. 

The pre-tax SEC-priced present value of future cash flows of reserve estimates as of June 30, 2018, discounted at 10% ("PV-10") (a non-GAAP financial measure defined below in "Information on Reserves and PV-10 Value"), was $124.9 million, a 57% decrease as compared to year-end 2017 primarily as a result of the sale of the WEHLU assets and lower proved undeveloped reserve volumes.  In accordance with SEC regulations, estimates of proved reserves as of June 30, 2018 were calculated using the 12-month unweighted arithmetic average of the first-day-of-the-month price for each month in the period July 1, 2017 through June 30, 2018.  For oil, the average 12-month West Texas Intermediate price utilized was $57.67 per barrel, compared to $51.34 per barrel for year-end 2017 SEC proved reserves, and for natural gas, the average 12-month Henry Hub price utilized was $2.92 per million British thermal unit ("MMBtu"), compared to $2.98 per MMBtu for year-end 2017 SEC proved reserves. 

For a discussion of PV-10 and the standardized measure of future net cash flows, see "Information on Reserves and PV-10 Value" below.

Conference Call

Gastar has scheduled a conference call for 9:00 a.m. Eastern Time (8:00 a.m. Central Time) on Friday, August 10, 2018.  Investors may participate in the call either by phone or audio webcast.

By Phone:

Dial 1-412-902-0030 at least 10 minutes before the call. A telephone replay will be available through August 24th by dialing 1-201-612-7415 and using the conference ID: 13682045.

   

By Webcast:

Visit the Investor Relations page of Gastar's website at www.gastar.com under "Events & Presentations." Please log on a few minutes in advance to register and download any necessary software. A replay will be available shortly after the call.

For more information, please contact Donna Washburn at Dennard-Lascar Associates at 713-529-6600 or e-mail dwashburn@DennardLascar.com.

About Gastar Exploration

Gastar Exploration Inc. is a pure-play Mid-Continent independent energy company engaged in the exploration, development and production of oil, condensate, natural gas and natural gas liquids in the United States. 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. For more information, visit Gastar's website at www.gastar.com.

Information on Reserves and PV-10 Value  

For the mid-year reserves at June 30, 2018 and year ended December 31, 2017, future cash inflows were computed using the 12-month un-weighted arithmetic average of the first-day-of-the-month prices for natural gas and oil (the "benchmark base prices") adjusted by lease in accordance with sales contracts and for energy content, quality, transportation, compression and gathering fees and regional price differentials, relating to the Company's proved reserves.  Benchmark base prices are held constant in accordance with SEC guidelines for the life of the wells.

PV-10 represents the present value, discounted at 10% per annum, of estimated future net revenue before income tax of our estimated proved reserves. PV-10 is a non-GAAP financial measure as defined by the SEC.  We believe that the presentation of PV-10 is relevant and useful to our investors because it presents the discounted future net cash flows attributable to our reserves prior to taking into account corporate future income taxes and our current tax structure.  We further believe investors and creditors use PV-10 as a basis for comparison of the relative size of our reserves as compared with other companies.

The financial measure most directly comparable to PV-10 is the standardized measure of future net cash flows ("Standardized Measure")  which takes into account future income taxes and our current tax structure.  As a result of our current net operating tax loss position, no future income taxes are anticipated and the PV-10 value shown should be reflective of our Standardized Measure. 

The Company's 2018 mid-year and 2017 year-end total proved reserves estimates were prepared by Wright & Company, Inc.

Forward Looking Statements

This news release includes "forward looking statements" within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934.  Forward looking statements give our current expectations, opinion, belief or forecasts of future events and performance.  A statement identified by the use of forward looking words including "may," "expects," "projects," "anticipates," "plans," "believes," "estimate," "will," "should," and certain of the other foregoing statements may be deemed forward-looking statements.  Although Gastar believes that the expectations reflected in such forward-looking statements are reasonable, these statements involve risks and uncertainties that may cause actual future activities and results to be materially different from those suggested or described in this news release.  These include risks inherent in natural gas and oil drilling and production activities, including risks with respect to continued low or further declining prices for natural gas and oil that could result in further downward revisions to the value of proved reserves or otherwise cause Gastar to further delay or suspend planned drilling and completion operations or reduce production levels which would adversely impact cash flow; risks relating to the availability of capital to fund drilling operations that can be adversely affected by debt service obligations, adverse drilling results, production declines and continued low or further declining prices for natural gas and oil; risks of fire, explosion, blowouts, pipe failure, casing collapse, unusual or unexpected formation pressures, environmental hazards, and other operating and production risks, which may temporarily or permanently reduce production or cause initial production or test results to not be indicative of future well performance or delay the timing of sales or completion of drilling operations; delays in receipt of drilling permits; risks relating to unexpected adverse developments in the status of properties; risks relating to the absence or delay in receipt of government approvals or third-party consents; risks relating to our ability to integrate acquired assets with ours and to realize the anticipated benefits from such acquisitions; risks associated with engagement in the exploration of strategic alternatives; and other risks described in Gastar's Annual Report on Form 10-K and other filings with the SEC, available at the SEC's website at www.sec.gov.  Our actual sales production rates can vary considerably from tested initial production rates depending upon completion and production techniques and our primary areas of operations are subject to natural steep decline rates. In addition, production information from our recently completed wells completed using our Gen 3 design is based on limited flow back history and therefore may not be fully indicative of sustained production rates or predictive of ultimate hydrocarbon recoveries.  By issuing forward looking statements based on current expectations, opinions, views or beliefs, Gastar has no obligation and, except as required by law, is not undertaking any obligation, to update or revise these statements or provide any other information relating to such statements.

Targeted expectations and guidance for the third quarter and full-year of 2018 are based upon the current capital expenditures budget planned for the remainder of 2018, which includes the Company's election to suspend its operated drilling program to, among other things, preserve capital for other cash needs, including, but not limited to, debt service while all strategic alternatives are considered or a possible restructuring of its debt and equity is completed.  The budget for the remainder of 2018 may be subject to further revision and reevaluation dependent upon future developments, including changes in commodity prices, drilling results, our liquidity position, availability of crews, supplies and production capacity, weather delays and significant changes in drilling costs.

Unless otherwise stated herein, equivalent volumes of production are based upon an energy equivalent ratio of six Mcf of natural gas to each barrel of liquids (oil, condensate and NGLs), which ratio is not reflective of relative value.  Our NGLs are sold as part of our wet gas subject to an incremental NGLs pricing formula based upon a percentage of NGLs extracted from our wet gas production.  Our reported production volumes reflect incremental post-processing NGLs volumes and residual gas volumes with which we are credited under our sales contracts.

- Financial Tables Follow –

GASTAR EXPLORATION INC.

CONSOLIDATED STATEMENTS OF OPERATIONS

 
 

For the Three Months Ended

June 30,

 

For the Six Months Ended

June 30,

 

2018

 

2017

 

2018

 

2017

 

(in thousands, except share and per share data)

REVENUES:

                     

Oil and condensate

$

16,079

 

$

12,744

 

$

37,061

 

$

24,934

Natural gas

 

1,451

   

2,345

   

3,632

   

4,933

NGLs

 

1,948

   

2,179

   

5,223

   

4,770

Total oil and condensate, natural gas and NGLs revenues

 

19,478

   

17,268

   

45,916

   

34,637

(Loss) gain on commodity derivatives contracts

 

(9,256)

   

5,378

   

(14,785)

   

6,678

Total revenues and other (loss) gain

 

10,222

   

22,646

   

31,131

   

41,315

EXPENSES:

                     

Production taxes

 

614

   

469

   

1,603

   

954

Lease operating expenses

 

4,771

   

5,146

   

12,280

   

10,218

Transportation, treating and gathering

 

   

440

   

   

751

Depreciation, depletion and amortization

 

7,588

   

6,051

   

16,566

   

10,703

Impairment of oil and natural gas properties

 

17,993

   

   

17,993

   

Accretion of asset retirement obligation

 

40

   

58

   

96

   

109

General and administrative expense

 

4,861

   

4,591

   

13,829

   

8,415

Total expenses

 

35,867

   

16,755

   

62,367

   

31,150

(LOSS) INCOME FROM OPERATIONS

 

(25,645)

   

5,891

   

(31,236)

   

10,165

OTHER (EXPENSE) INCOME:

                     

Interest expense

 

(10,200)

   

(8,736)

   

(20,137)

   

(19,585)

Loss on early extinguishment of debt

 

   

   

   

(12,172)

Investment income and other

 

23

   

66

   

40

   

115

LOSS BEFORE PROVISION FOR INCOME TAXES

 

(35,822)

   

(2,779)

   

(51,333)

   

(21,477)

Provision for income taxes

 

   

   

   

NET LOSS

 

(35,822)

   

(2,779)

   

(51,333)

   

(21,477)

Dividends on preferred stock

 

(3,618)

   

(3,619)

   

(7,236)

   

(7,237)

Undeclared cumulative dividends on preferred stock

 

   

   

   

NET LOSS ATTRIBUTABLE TO COMMON STOCKHOLDERS

$

(39,440)

 

$

(6,398)

 

$

(58,569)

 

$

(28,714)

NET LOSS PER SHARE OF COMMON STOCK ATTRIBUTABLETO COMMON STOCKHOLDERS:

                     

Basic

$

(0.19)

 

$

(0.03)

 

$

(0.28)

 

$

(0.16)

Diluted

$

(0.19)

 

$

(0.03)

 

$

(0.28)

 

$

(0.16)

WEIGHTED AVERAGE SHARES OF COMMONSTOCK OUTSTANDING:

                     

Basic

 

211,744,943

   

199,547,446

   

210,839,194

   

181,430,409

Diluted

 

211,744,943

   

199,547,446

   

210,839,194

   

181,430,409

 

GASTAR EXPLORATION INC.

CONSOLIDATED BALANCE SHEETS

 
 

June 30,

 

December 31,

 

2018

 

2017

 

(in thousands, except share and per
share data)

ASSETS

         

CURRENT ASSETS:

         

Cash and cash equivalents

$

51,072

 

$

13,266

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

 

18,156

   

38,575

Commodity derivative contracts

 

140

   

1,370

Prepaid expenses

 

640

   

960

Total current assets

 

70,008

   

54,171

PROPERTY, PLANT AND EQUIPMENT:

         

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

         

Unproved properties, excluded from amortization

 

141,027

   

131,955

Proved properties

 

1,313,792

   

1,344,329

Total natural gas and oil properties

 

1,454,819

   

1,476,284

Furniture and equipment

 

3,604

   

3,838

Total property, plant and equipment

 

1,458,423

   

1,480,122

Accumulated depreciation, depletion and amortization

 

(1,189,332)

   

(1,155,027)

Total property, plant and equipment, net

 

269,091

   

325,095

OTHER ASSETS:

         

Restricted cash

 

25

   

370

Advances to operators

 

79

   

82

Other

 

-

   

405

Total other assets

 

104

   

857

TOTAL ASSETS

$

339,203

 

$

380,123

LIABILITIES AND STOCKHOLDERS' DEFICIT

         

CURRENT LIABILITIES:

         

Accounts payable

$

13,026

 

$

24,382

Revenue payable

 

16,756

   

11,823

Accrued interest

 

7,558

   

7,298

Accrued drilling and operating costs

 

10,258

   

9,381

Advances from non-operators

 

757

   

1,445

Commodity derivative contracts

 

11,688

   

4,416

Commodity derivative premium payable

 

68

   

135

Other accrued liabilities

 

5,010

   

2,706

Total current liabilities

 

65,121

   

61,586

LONG-TERM LIABILITIES:

         

Long-term debt

 

362,752

   

342,952

Commodity derivative contracts

 

4,182

   

2,572

Asset retirement obligation

 

2,431

   

4,841

Total long-term liabilities

 

369,365

   

350,365

Commitments and contingencies

         

STOCKHOLDERS' DEFICIT:

         

Preferred stock, 40,000,000 shares authorized

         

Series A Preferred Stock, par value $0.01 per share; 10,000,000 shares  designated; 4,045,000 shares issued and outstanding at June 30, 2018 and December 31, 2017, respectively, with liquidation preference of $25.00 per share

 

41

   

41

Series B Preferred Stock, par value $0.01 per share; 10,000,000 shares designated; 2,140,000 shares issued and outstanding at June 30, 2018 and December 31, 2017, respectively, with liquidation preference of $25.00 per share

 

21

   

21

Common stock, par value $0.001 per share; 800,000,000 shares authorized at June 30, 2018 and December 31, 2017, respectively; 219,175,611 and 218,874,418 shares issued and outstanding at June 30, 2018 and December 31, 2017, respectively

 

219

   

219

Additional paid-in capital

 

820,699

   

819,554

Accumulated deficit

 

(916,263)

   

(851,663)

Total stockholders' deficit

 

(95,283)

   

(31,828)

TOTAL LIABILITIES AND STOCKHOLDERS' DEFICIT

$

339,203

 

$

380,123

 

GASTAR EXPLORATION INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

 
 

For the Six Months Ended

June 30,

 

2018

 

2017

 

(in thousands)

CASH FLOWS FROM OPERATING ACTIVITIES:

         

Net loss

$

(51,333)

 

$

(21,477)

Adjustments to reconcile net loss to net cash provided by (used in)operating activities:

         

Depreciation, depletion and amortization

 

16,566

   

10,703

Impairment of natural gas and oil properties

 

17,993

   

Stock-based compensation

 

2,896

   

2,199

Total loss (gain) on commodity derivatives contracts

 

14,785

   

(6,678)

Cash settlements of matured commodity derivative contracts, net

 

(3,446)

   

3,553

Cash premiums paid for commodity derivatives contracts

 

(552)

   

Amortization of deferred financing costs and debt discount

 

6,518

   

4,927

Paid-in-kind interest

 

13,282

   

Accretion of asset retirement obligation

 

96

   

109

Loss on sale of furniture and equipment

 

7

   

Loss on early extinguishment of debt

 

   

12,172

Changes in operating assets and liabilities:

         

Accounts receivable

 

19,678

   

(29,115)

Prepaid expenses

 

232

   

30

Accounts payable and accrued liabilities

 

2,529

   

6,983

Net cash provided by (used in) operating activities

 

39,251

   

(16,594)

CASH FLOWS FROM INVESTING ACTIVITIES:

         

Development and purchase of oil and natural gas properties

 

(83,405)

   

(48,274)

Acquisition of oil and natural gas properties

 

(144)

   

(54,462)

Proceeds from sale of oil and natural gas properties

 

96,304

   

26,780

Application of proceeds from non-operators

 

(688)

   

(609)

Advances to operators

 

(15)

   

Purchase of furniture and equipment

 

(30)

   

(393)

Net cash provided by (used in) investing activities

 

12,022

   

(76,958)

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)

Loss on early extinguishment of debt

 

   

(7,011)

Proceeds from issuance of common shares, net of issuance costs

 

   

56,367

Dividends on preferred stock

 

(12,061)

   

(18,092)

Deferred financing charges

 

   

(9,971)

Decrease (increase) in restricted cash

 

345

   

(369)

Tax withholding related to restricted stock award vestings

 

(1,240)

   

(585)

Other

 

(511)

   

0

Net cash (used in) provided by financing activities

 

(13,467)

   

60,709

NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS

 

37,806

   

(32,843)

CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD

 

13,266

   

71,529

CASH AND CASH EQUIVALENTS, END OF PERIOD

$

51,072

 

$

38,686

NON-GAAP FINANCIAL INFORMATION AND RECONCILIATION

We use both GAAP and certain non-GAAP financial measures to assess performance.  Generally, a non-GAAP financial measure is a numerical measure of a company's performance, financial position or cash flows that either excludes or includes amounts that are not normally excluded or included in the most directly comparable measure calculated and presented in accordance with GAAP.  Our management believes that these non-GAAP measures provide useful supplemental information to investors in order that they may evaluate our financial performance using the same measures as management.  These non-GAAP financial measures should not be considered as a substitute for, or superior to, measures of financial performance prepared in accordance with GAAP.  In evaluating these measures, investors should consider that the methodology applied in calculating such measures may differ among companies and analysts.  A reconciliation is provided below outlining the differences between these non-GAAP measures and their most directly comparable financial measure calculated in accordance with GAAP.

Reconciliation of Net Loss to Adjusted Net Loss:

 
 

For the Three Months Ended

June 30,

 

For the Six Months Ended

June 30,

 

2018

 

2017

 

2018

 

2017

 

(in thousands, except share and per share data)

NET LOSS ATTRIBUTABLE TO COMMON STOCKHOLDERS

$

(39,440)

 

$

(6,398)

 

$

(58,569)

 

$

(28,714)

SPECIAL ITEMS:

                     

Losses (gains) related to the change in mark to market value for outstanding commodity derivatives contracts

 

6,133

   

(3,356)

   

9,459

   

(2,774)

Impairment of oil and natural gas properties

 

17,993

   

   

17,993

   

Loss on early extinguishment of debt

 

   

   

   

12,172

Non-recurring severance costs

 

   

   

3,545

   

                       

ADJUSTED NET LOSS ATTRIBUTABLE TO COMMON STOCKHOLDERS

$

(15,314)

 

$

(9,754)

 

$

(27,572)

 

$

(19,316)

                       

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

                     

Basic

$

(0.07)

 

$

(0.05)

 

$

(0.13)

 

$

(0.11)

Diluted

$

(0.07)

 

$

(0.05)

 

$

(0.13)

 

$

(0.11)

WEIGHTED AVERAGE SHARES OF COMMON STOCK

                     

Basic

 

211,744,943

   

199,547,446

   

210,839,194

   

181,430,409

Diluted

 

211,744,943

   

199,547,446

   

210,839,194

   

181,430,409

 

Reconciliation of Cash Flows before Working Capital Changes and to Adjusted Cash Flows from Operations:

 
 

For the Three Months Ended

June 30,

 

For the Six Months Ended

June 30,

 

2018

 

2017

 

2018

 

2017

 

(in thousands)

CASH FLOWS FROM OPERATING ACTIVITIES:

                     

Net loss

$

(35,822)

 

$

(2,779)

 

$

(51,333)

 

$

(21,477)

Adjustments to reconcile net loss to net cash provided by operating activities:

                     

Depreciation, depletion and amortization

 

7,588

   

6,051

   

16,566

   

10,703

Impairment of oil and natural gas properties

 

17,993

   

   

17,993

   

Stock-based compensation

 

1,172

   

1,203

   

2,896

   

2,199

Mark to market of commodity derivatives contracts:

                     

Total loss (gain) on commodity derivatives contracts

 

9,256

   

(5,378)

   

14,785

   

(6,678)

Cash settlements of matured commodity derivatives contracts, net

 

(2,099)

   

1,870

   

(3,446)

   

3,553

Cash premiums paid for commodity derivatives contracts

 

   

   

(552)

   

Amortization of deferred financing costs and debt discount

 

3,341

   

3,217

   

6,518

   

4,927

Paid in kind interest

 

6,653

   

   

13,282

   

Accretion of asset retirement obligation

 

40

   

58

   

96

   

109

Loss on sale of assets

 

7

   

   

7

   

Loss on early extinguishment of debt

 

   

   

   

12,172

Cash flows from operations before working capital changes

 

8,129

   

4,242

   

16,812

   

5,508

Dividends on preferred stock

 

(3,618)

   

(3,619)

   

(7,236)

   

(7,237)

Paid in kind interest

 

(6,653)

   

   

(13,282)

   

Non-recurring severance costs

 

   

   

3,545

   

Adjusted cash flows (used in) provided by operations

$

(2,142)

 

$

623

 

$

(161)

 

$

(1,729)

 

Reconciliation of Net Loss to Adjusted Earnings Before Interest, Income Taxes, Depreciation, Depletion and Amortization ("Adjusted EBITDA"):

 
 

For the Three Months Ended

June 30,

 

For the Six Months Ended

June 30,

 

2018

 

2017

 

2018

 

2017

 

(in thousands)

NET LOSS ATTRIBUTABLE TO COMMON STOCKHOLDERS

$

(39,440)

 

$

(6,398)

 

$

(58,569)

 

$

(28,714)

Interest expense

 

10,200

   

8,736

   

20,137

   

19,585

Loss on early extinguishment of debt

 

   

   

   

12,172

Depreciation, depletion and amortization

 

7,588

   

6,051

   

16,566

   

10,703

Impairment of oil and natural gas properties

 

17,993

   

   

17,993

   

EBITDA

 

(3,659)

   

8,389

   

(3,873)

   

13,746

Dividends on preferred stock

 

3,618

   

3,619

   

7,236

   

7,237

Accretion of asset retirement obligation

 

40

   

58

   

96

   

109

Losses (gains) related to the change in mark to market value for outstanding commodity derivatives contracts

 

6,133

   

(3,356)

   

9,459

   

(2,774)

Non-cash stock-based compensation expense

 

1,172

   

1,203

   

2,896

   

2,199

Investment income and other

 

(23)

   

(66)

   

(40)

   

(115)

Non-recurring severance costs

 

   

   

3,545

   

ADJUSTED EBITDA

$

7,281

 

$

9,847

 

$

19,319

 

$

20,402

 

Contacts:
Gastar Exploration Inc.
Michael A. Gerlich, Chief Financial Officer
713-739-1800 / mgerlich@gastar.com

Investor Relations Counsel:
Lisa Elliott, DennardLascar Investor Relations
713-529-6600 / lelliott@DennardLascar.com

 

Cision View original content:http://www.prnewswire.com/news-releases/gastar-exploration-announces-second-quarter-2018-results-300695061.html

SOURCE Gastar Exploration Inc.