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PetroQuest Energy Announces Second Quarter Results And Updates Operations And Hedging

PQ

LAFAYETTE, La., Aug. 6, 2013 /PRNewswire/ -- PetroQuest Energy, Inc. (NYSE: PQ) (the "Company") closed its previously announced acquisition of certain shallow water Gulf of Mexico shelf oil and gas assets on July 3, 2013, and accordingly, the operating results reported for the second quarter of 2013 do not include the impact of such acquisition.

The Company announced today that it recorded net income available to common stockholders for the quarter ended June 30, 2013 of $3,662,000, or $0.06 per share, compared to second quarter 2012 net loss available to common stockholders of $54,520,000, or $0.87 per share. For the first six months of 2013, the Company reported  net income available to common stockholders of $6,269,000, or $0.10 per share, compared to a net loss available to common stockholders of $73,128,000, or $1.17 per share, for the 2012 period. During the second quarter and six month periods of 2012, the Company recognized non-cash ceiling test write-downs of $53,485,000 and $73,596,000, respectively, as a result of the impact of low natural gas prices on the future discounted net cash flows from its estimated proved reserves.

Discretionary cash flow for the second quarter of 2013 was $19,809,000, as compared to $20,068,000 for the comparable 2012 period.  For the first six months of 2013, discretionary cash flow was $38,441,000 compared to discretionary cash flow of $39,716,000 for the first six months of 2012. See the attached schedule for a reconciliation of net cash flow provided by operating activities to discretionary cash flow.

Production for the second quarter of 2013 was 8.7 Bcfe, compared to 8.4 Bcfe for the comparable period of 2012. For the first six months of 2013, production was 16.9 Bcfe, compared to 16.6 Bcfe for the comparable period of 2012.  Adjusted for the Fayetteville asset divestiture in December 2012, production during the second quarter and the first six months of 2013 was 9% higher than each of the corresponding 2012 periods. The increase in production during the 2013 periods is primarily due to additional La Cantera production as well as higher liquids rich Woodford production.

Stated on an Mcfe basis, unit prices including the effects of hedges for the second quarter of 2013 were $4.39  per Mcfe, as compared to $3.97 per Mcfe in the second quarter of 2012.  For the first six months of 2013, unit prices including the effects of hedges, were $4.37 per Mcfe, as compared to $4.19 per Mcfe for the first six months of 2012. Oil and gas sales during the second quarter of 2013 were $38,076,000, as compared to $33,376,000, in the second quarter of 2012. For the first six months of 2013, oil and gas sales were $74,052,000 compared to oil and gas sales of $69,373,000 for the first six months of 2012.

Lease operating expenses ("LOE") for the second quarter of 2013 decreased to $8,837,000, as compared to $9,085,000 in the second quarter of 2012.  LOE per Mcfe was $1.02 for the second quarter of 2013, as compared to $1.08 in the second quarter of 2012. For the first six months of 2013, lease operating expenses decreased to $1.10 per Mcfe from $1.13 per Mcfe in the comparable period of 2012. The decline in LOE during the 2013 periods is primarily the result of a reduction in workovers attributable to repairs and maintenance. 

Depreciation, depletion and amortization ("DD&A") on oil and gas properties for the second quarter of 2013 was $1.64 per Mcfe, as compared to $1.84 per Mcfe in the second quarter of 2012. For the first six months of 2013, DD&A on oil and gas properties was $1.59 per Mcfe compared to $1.84 per Mcfe for the comparable period of 2012.  The decrease in the per unit DD&A rate is primarily the result of ceiling test write-downs recognized during 2012.

Interest expense for the second quarter of 2013 increased to $3,116,000, as compared to $2,413,000 in the second quarter of 2012. For the first six months of 2013, interest expense was $5,980,000, compared to $4,683,000 for the comparable period of 2012. The increase in interest expense was due to increased borrowings outstanding under the bank credit facility.

Production taxes for the second quarter of 2013 were $1,481,000, as compared to ($1,917,000) in the second quarter of 2012.  For the first six months of 2013, production taxes were $2,509,000 compared to ($768,000) for the comparable period of 2012. The increases during the 2013 periods as compared to the corresponding 2012 periods were the result of recording a receivable of $2,717,000 during the second quarter of 2012 for refunds relative to severance tax previously paid on our Oklahoma horizontal wells.

General and administrative expenses during the quarter and six months ended June 30, 2013 totaled $6,351,000 and $11,067,000, respectively, as compared to expenses of $5,999,000 and $11,578,000 during the comparable 2012 periods. General and administrative expenses for the quarter ended June 30, 2013 included $996,000 of transaction costs associated with the Gulf of Mexico acquisition closed on July 3, 2013.

The following table sets forth certain information with respect to the oil and gas operations of the Company for the three and six month periods ended June 30, 2013 and 2012:


Three Months Ended June 30,

Six Months Ended June 30,


2013

2012

2013

2012

Production (1) :





Oil (Bbls)

115,697

116,037

241,420

257,312

Gas (Mcf)

6,731,754

6,945,466

13,168,349

13,674,781

Ngl (Mcfe)

1,256,814

763,302

2,321,461

1,356,437

Total Production (Mcfe)

8,682,750

8,404,990

16,938,330

16,575,090

Total Daily Production  (Mcfe/d)

95,415

92,363

93,582

91,072

Sales:





Total oil sales

$     12,024,212

$    12,831,097

$    25,168,522

$    28,340,054

Total gas sales

20,247,600

15,457,658

36,970,632

30,737,611

Total ngl sales

5,804,172

5,087,135

11,913,118

10,295,240

Total oil and gas sales

$     38,075,984

$    33,375,890

$    74,052,272

$    69,372,905

Average sales prices:





Oil (per Bbl)

$            103.93

$           110.58

$           104.25

$           110.14

Gas (per Mcf)

3.01

2.23

2.81

2.25

Ngl (per Mcfe)

4.62

6.66

5.13

7.59

Per Mcfe

4.39

3.97

4.37

4.19



(1)

Production during the three and six month 2012 periods included 523,353 Mcfe (5,083 Mcfe/d) and 985,880 Mcfe (5,417 Mcfe/d), respectively from Fayetteville Shale assets divested in December 2012.

The above sales and average sales prices include increases (decreases) to revenue related to the settlement of gas hedges of ($877,000) and $3,230,000, Ngl hedges of zero and $232,000 and oil hedges of ($1,000) and $415,000 for the three months ended June 30, 2013 and 2012, respectively.  The above sales and average sales prices include increases (reductions) to revenue related to the settlement of gas hedges of ($345,000)  and $5,385,000, Ngl hedges of zero  and $232,000, and oil hedges of ($146,000)  and $362,000 , respectively.

The following initiates guidance for the third quarter of 2013:


Guidance for

Description

3rd Quarter 2013



Production volumes (MMcfe/d)

117 - 125



Percent Gas

75%

Percent Oil

14%

Percent NGL

11%



Expenses:


   Lease operating expenses (per Mcfe)

$1.15 - $1.25

   Production taxes (per Mcfe)

$0.10 - $0.15

   Depreciation, depletion and amortization (per Mcfe)

$2.00 - $2.10

   General and administrative (in millions) (1)

$8.0 - $9.0

   Interest expense (in millions)

$7.5 - $8.0



(1) Includes non-cash stock compensation estimate of $1.4 million and estimated transaction costs of $2.5 million.

The following updates guidance for 2013:


Guidance for

Description

2013



Production volumes (MMcfe/d)

105 - 110



Percent Natural Gas

75%

Percent Oil

12%

Percent NGL

13%



Expenses:


     Lease operating expenses (per Mcfe)

$1.15 - $1.25

     Production taxes (per Mcfe)

$0.10 - $0.15

     Depreciation, depletion and amortization (per Mcfe)

$1.80 - $1.90

     General and administrative (in millions) (1)

$24 - $26

     Interest expense (in millions)

$21 - $22

  2013 Capital Expenditures (in millions) (2)

$100 - $110


(1) Includes non-cash stock compensation estimate of $4.3 million and estimated transaction costs of $3.5 million.

(2) Excludes acquisition costs for the Gulf of Mexico properties.

Operations Update
In the Gulf of Mexico, the Company has modified production equipment on one of its wells at its recently acquired West Delta 89 field. As a result, the Company has increased the gross daily production from this well (NRI -51%) by approximately 550 barrels of oil.  In addition, the Company expects to recomplete two wells at the West Delta 89 field in approximately 2-3 weeks after evaluating whether these wells have depleted the currently completed zone.  Additionally, the Company has two wells at Ship Shoal 238 that have been completed and are awaiting pipeline interconnect, which is scheduled to occur in approximately one week.  The Company estimates that its recently acquired properties are currently producing 1,300 barrels of oil, net per day and 18,000 Mcf of gas, net per day.  The Company expects that once the two recompletions at West Delta 89 have been performed and the pipeline interconnect has been completed at Ship Shoal 238 the total production from the recently acquired properties will be approximately 2,100 barrels of oil, net per day and 24,000 Mcf of gas, net per day.

The Company's non-operated Galveston Island prospects (WI – 20%) logged pay, but were determined to be non-commercial.  The Company estimates that its total net cost for these two wells was approximately $1.5 million.  

In the Gulf Coast, the Company recently commenced production from its third well at its La Cantera field, the Broussard Estates #3 (NRI – 17%).  The well is currently flowing at a gross daily rate of approximately 28,000 Mcf of gas, 660 barrels of natural gas liquids and 540 barrels of oil.  The Company's mid-stream partner has completed the installation of a four mile pipeline to the north, which has resolved the previous takeaway capacity constraints from the field.   As a result, the Company's total gross daily production from its three La Cantera wells (NRI – 17%) is approximately 102,000 Mcf of gas, 2,400 barrels of natural gas liquids and 2,000 barrels of oil.  In addition, the Company's mid-stream partner is currently upgrading its processing plant, which is expected to be completed in November of 2013. Once the upgraded processing plant is online, the Company expects to increase its natural gas liquids recoveries from La Cantera.

The Company's Thunder Bayou prospect located approximately two miles north of the La Cantera project is expected to spud during the fourth quarter of 2013.  The Company has fully evaluated the recent 3-D seismic shoot and is currently working on drilling and development plans for this potentially high impact project.  The Company is scheduled to have its unitization hearing this month to finalize the drilling unit.  In addition, the Company's two liquids focused prospects, Tokay (WI -75%) and Sawgrass (WI-35%) are expected to spud in September and October, respectively.

In the Woodford, the Company has two dry gas wells (NRI – 39%) that have reached total depth and are expected to be completed in approximately three weeks. The Company is in the process of mobilizing a rig to the liquids rich area of its leasehold position.  In addition, the Company expects to have a second rig in this part of the trend by early fourth quarter of 2013 and a third rig by the first quarter of 2014.  In total, the Company expects to drill approximately 50 gross wells in 2014, which is a 213% increase from its expected 2013 gross well count of 16 wells. The Company continues to acquire additional acreage in the liquids portion of the trend and has increased its position by over 400% during 2013.  The Company estimates that it has added approximately 17,000 net JV acres year to date growing its liquids rich leasehold position to approximately 21,000 net JV acres. In addition, the Company has recently completed shooting a 3-D seismic survey on a portion of this acreage.  

In East Texas, the Company's PQ #9 well (NRI – 76%) that was completed in early April and achieved a 24 hour max rate of 6,353 Mcf of gas and 458 barrels of natural gas liquids is currently producing at a gross daily rate of 5,298 Mcf of gas and 382 barrels of natural gas liquids.  The Company is in the process of selecting a rig for this trend and expects to reinitiate its horizontal Cotton Valley program during the fourth quarter of 2013.  In total, the Company expects to drill 8-10 gross wells in 2014.

In the Mississippian Lime, the Company recently received its 3-D seismic data from its Kay County survey and has commenced the evaluation process of the newly acquired data.  In addition, the Company is expected to commence its Pawnee County 3-D seismic survey in approximately 4-5 weeks. The Company will evaluate these data sets and determine development plans after incorporating both PetrQuest and industry well results with the seismic data.   

Hedging Update
The Company recently initiated the following oil hedging transactions:



Instrument





Production Period


Type


Daily Volumes


Price

Oil:







Jul 13 - Dec 13


Swap


250 Bbls


$98.80 (1)

Aug 13 - Dec 13


Swap


250 Bbls


$103.70 (1)

Sep 13 - Dec 13


Swap


250 Bbls


$106.25 (2)

2014


Swap


100 Bbls


$95.15 (1)

2014


Swap


100 Bbls


$100.45 (2)








    (1)     WTI Index







    (2)     LLS Index







The Company has approximately 172,000 barrels of oil and 6.9 Bcf of gas hedged for the remainder of 2013 at an average floor price of $101.73 /Bbl and $3.63/Mcf, respectively.  In addition, the Company has approximately 164,000 barrels of oil and 3.6 Bcf of gas hedged for 2014 at an average floor price of $94.86/Bbl and $4.08/Mcf, respectively.

Management Statement
"With the closing of the Gulf of Mexico acquisition in July, we view the third quarter of 2013 as an inflection point in our oil production and associated cash flow.  We have taken advantage of the recent rally in crude prices by layering in multiple hedging contracts at more attractive prices than we used in our valuation of the assets," said Charles T. Goodson, Chairman, Chief Executive Officer and President. " On a pro forma basis, the acquired assets would have provided a 60% increase to our first quarter 2013 EBITDA on daily production of 967 barrels of oil and 19 MMcfe of gas.  Over the next several weeks, we expect to increase oil production from the acquired assets to 2,100 barrels per day, which should translate into a material cash flow contribution."

About the Company
PetroQuest Energy, Inc. is an independent energy company engaged in the exploration, development, acquisition and production of oil and natural gas reserves in the Arkoma Basin, Wyoming, Texas, South Louisiana and the shallow waters of the Gulf of Mexico.  PetroQuest's common stock trades on the New York Stock Exchange under the ticker PQ.

Forward-Looking Statements
This news release contains "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended.  These forward-looking statements are subject to certain risks, trends and uncertainties that could cause actual results to differ materially from those projected.  Among those risks, trends and uncertainties are our ability to integrate our recently completed acquisitions with our operations and realize the anticipated benefits from the acquisitions, any unexpected costs or delays in connection with the acquisitions,  our ability to find oil and natural gas reserves that are economically recoverable, the volatility of oil and natural gas prices and significantly depressed natural gas prices since the middle of 2008, the uncertain economic conditions in the United States and globally, the declines in the values of our properties that have resulted in and may in the future result in additional ceiling test write-downs, our ability to replace reserves and sustain production, our estimate of the sufficiency of our existing capital sources, our ability to raise additional capital to fund cash requirements for future operations, the uncertainties involved in prospect development and property acquisitions or dispositions and in projecting future rates of production or future proved, probable and possible reserves, the timing of development expenditures and drilling of wells, hurricanes and other natural disasters, changes in laws and regulations as they relate to our operations, including our fracing operations in shale plays or our operations in the Gulf of Mexico, and the operating hazards attendant to the oil and gas business.  In particular, careful consideration should be given to cautionary statements made in the various reports PetroQuest has filed with the Securities and Exchange Commission. PetroQuest undertakes no duty to update or revise these forward-looking statements.
Click here for more information: "http://www.petroquest.com/news.html?=BizID=1690&1=1"

 

PETROQUEST ENERGY, INC.

Consolidated Balance Sheets

(unaudited)

(Amounts in Thousands)



Three Months Ended

Twelve Months Ended


June 30, 2013

December 31, 2012

ASSETS



Current assets:



Cash and cash equivalents

$                        8,113

$                      14,904

Revenue receivable

14,007

17,742

Joint interest billing receivable

32,281

42,595

Other receivable

9,208

Derivative asset

1,999

830

Prepaid drilling costs

2,499

1,698

Other current assets

6,182

2,607

Total current assets

65,081

89,584

Property and equipment:



Oil and gas properties:



Oil and gas properties, full cost method

1,791,459

1,734,477

Unevaluated oil and gas properties

68,910

71,713

Accumulated depreciation, depletion and amortization

(1,508,820)

(1,472,244)

Oil and gas properties, net

351,549

333,946

Other property and equipment

12,627

12,370

Accumulated depreciation of other property and equipment

(8,144)

(7,607)

Total property and equipment

356,032

338,709

Derivative asset

388

Other assets, net of accumulated depreciation and amortization of $4,647 and $4,240, respectively

5,065

5,110

Deposit on acquired assets

5,000

Total assets

$                    431,566

$                    433,403

LIABILITIES AND STOCKHOLDERS' EQUITY



Current liabilities:



Accounts payable to vendors

$                      39,923

$                      58,960

Advances from co-owners

11,911

20,459

Oil and gas revenue payable

26,042

26,175

Accrued interest and preferred stock dividend

6,209

6,190

Asset retirement obligation

3,823

2,351

Derivative liability

205

233

Other accrued liabilities

6,408

6,535

Total current liabilities

94,521

120,903

Bank debt

65,000

50,000

10% Senior Notes

150,000

150,000

Asset retirement obligation

25,487

24,909

Commitments and contingencies



Stockholders' equity:



Preferred stock, $.001 par value; authorized 5,000 shares; issued and outstanding 1,495 shares

1

1

Common stock, $.001 par value; authorized 150,000 shares; issued and outstanding 62,993 and 62,768 shares, respectively

63

63

Paid-in capital

278,335

276,534

Accumulated other comprehensive income

1,418

521

Accumulated deficit

(183,259)

(189,528)

Total stockholders' equity

96,558

87,591

Total liabilities and stockholders' equity

$                    431,566

$                    433,403

 

PETROQUEST ENERGY, INC.

Consolidated Statements of Operations

(unaudited)

(Amounts in Thousands, Except Per Share Data)





Three Months Ended

Six Months Ended


June 30, 2013

June 30, 2012

June 30, 2013

June 30, 2012

Revenues:





Oil and gas sales

$       38,076

$       33,376

$       74,052

$       69,373

Gas gathering revenue

26

37

59

81


38,102

33,413

74,111

69,454

Expenses:





Lease operating expenses

8,837

9,085

18,556

18,750

Production taxes

1,481

(1,917)

2,509

(768)

Depreciation, depletion and amortization

14,536

15,762

27,407

30,992

Ceiling test write-down

53,485

73,596

General and administrative

6,351

5,999

11,067

11,578

Accretion of asset retirement obligation

328

517

660

1,017

Interest expense

3,116

2,413

5,980

4,683


34,649

85,344

66,179

139,848

Other income (expense):





Other income

62

123

256

272

Derivative income (expense)

594

(375)

157

(375)


656

(252)

413

(103)

Income (loss) from operations

4,109

(52,183)

8,345

(70,497)

Income tax expense (benefit)

(840)

1,049

(491)

61

Net income (loss)

4,949

(53,232)

8,836

(70,558)

Preferred stock dividend

1,287

1,288

2,567

2,570

Net income (loss) available to common stockholders

$         3,662

$     (54,520)

$         6,269

$     (73,128)

Earnings per common share:





Basic





Net income (loss) per share

$           0.06

$         (0.87)

$           0.10

$         (1.17)

Diluted





Net income (loss) per share

$           0.06

$         (0.87)

$           0.10

$         (1.17)

Weighted average number of common shares:





Basic

62,963

62,363

62,899

62,289

Diluted

63,130

62,363

63,084

62,289

                                                                                                 

PETROQUEST ENERGY, INC.

Consolidated Statements of Cash Flows

(unaudited)

(Amounts in Thousands)


Six Months Ended


June 30, 2013

June 30, 2012

Cash flows from operating activities:



Net income (loss)

$        8,836

$      (70,558)

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



Deferred tax expense (benefit)

(491)

61

Depreciation, depletion and amortization

27,407

30,992

Ceiling test writedown

73,596

Accretion of asset retirement obligation

660

1,017

Share based compensation expense

1,780

3,838

Amortization costs and other

406

395

Non-cash derivative (income) expense

(157)

375

Payments to settle asset retirement obligations

(94)

(2,450)

Changes in working capital accounts:



Revenue receivable

3,735

3,384

Prepaid drilling and pipe costs

(801)

2,548

Joint interest billing receivable

10,314

8,962

Accounts payable and accrued liabilities

(19,195)

4,602

Advances from co-owners

(8,548)

(11,341)

Other

(3,237)

(3,153)

Net cash provided by operating activities

20,615

42,268

Cash flows used in investing activities:



Investment in oil and gas properties

(52,740)

(75,825)

Investment in other property and equipment

(257)

Deposit on acquired properties

(5,000)

Sale of oil and gas properties

18,914

275

Sale of unevaluated oil and gas properties

6,083

Net cash used in investing activities

(39,083)

(69,467)

Cash flows used in financing activities:



Net payments for share based compensation

20

(383)

Deferred financing costs

(774)

(12)

Payment of preferred stock dividend

(2,569)

(2,570)

Proceeds from bank borrowings

40,000

45,000

Repayment of bank borrowings

(25,000)

(27,500)

Net cash provided by financing activities

11,677

14,535

Net decrease  in cash and cash equivalents

(6,791)

(12,664)

Cash and cash equivalents, beginning of period

14,904

22,263

Cash and cash equivalents, end of period

$          8,113

$          9,599

Supplemental disclosure of cash flow information:



Cash paid during the period for:



Interest

$          8,321

$          7,871

Income taxes

$               40

$               15

 

PETROQUEST ENERGY, INC.

Non-GAAP Disclosure Reconciliation

(Amounts In Thousands)




Three Months Ended


Six Months Ended



June 30,


June 30,



2013

2012


2013

2012

Net income (loss)


$   4,949

$ (53,232)


$   8,836

$ (70,558)








Reconciling items:







      Deferred tax expense (benefit)


(840)

1,049


(491)

61

      Depreciation, depletion and amortization


14,536

15,762


27,407

30,992

      Ceiling test writedown


-

53,485


-

73,596

      Non-cash derivative (income) expense


(594)

375


(157)

375

      Accretion of asset retirement obligation


328

517


660

1,017

      Share based compensation expense


1,224

1,915


1,780

3,838

      Amortization costs and other


206

197


406

395

Discretionary cash flow


19,809

20,068


38,441

39,716

      Changes in working capital accounts


(8,292)

9,917


(17,732)

5,002

      Settlement of asset retirement obligations


(22)

(1,668)


(94)

(2,450)








Net cash flow provided by operating activities


$ 11,495

$  28,317


$ 20,615

$  42,268

Note:   

Management believes that discretionary cash flow is relevant and useful information, which is commonly used by analysts, investors and other interested parties in the oil and gas industry as a financial indicator of an oil and gas company's ability to generate cash used to internally fund exploration and development activities and to service debt.  Discretionary cash flow is not a measure of financial performance prepared in accordance with generally accepted accounting principles ("GAAP") and should not be considered in isolation or as an alternative to net cash flow provided by operating activities.  In addition, since discretionary cash flow is not a term defined by GAAP, it might not be comparable to similarly titled measures used by other companies.

 

SOURCE PetroQuest Energy, Inc.


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