Goodrich Petroleum Announces Financial Results And Operational Update

    Goodrich Petroleum Announces Financial Results And Operational Update

PR Newswire

HOUSTON, Nov. 4, 2013

HOUSTON, Nov. 4, 2013 /PRNewswire/ -- Goodrich Petroleum Corporation (NYSE:
GDP) (the "Company") today announced financial and operating results for the
quarter ended September 30, 2013 and provided an operational update.

Tuscaloosa Marine Shale ("TMS"):

  oPreliminary 2014 capital expenditure budget allocates $300 million for the
    TMS to drill up to 31 gross (24 net) wells with five operated rigs running
    in the playby the end of 2014 pending continued success
  oThe Company drilled its Huff 18-7H No. 1 (97% WI) well with usable lateral
    of approximately 5,400 feet. The Company drilled the curve and lateral in
    arecord time of 12 days but has experienced completion delays due to
    temporarily sticking the drill pipe shortly after reaching total depth.
    The Company successfully freed the drill pipe and is currently cleaning
    out the wellbore in preparation of running production casing.The cleanout
    of the wellbore is expected to be completed withing the next few days
  oCumulative production from the Company's Crosby well has reached 138,000
    barrels of oil equivalent ("BOE", 90% oil) in 8.5 months, and five of the
    last six completed wells are currently producingat or above the Company's
    600,000 BOE type curve (See current Management Presentation posted on
    website)
  oThe Company currently has two rigs running in the play and has commenced
    drilling operations on its Weyerhaeuser 51H-1 (67% WI) well in St. Helena
    Parish, Louisiana, the initial well of three consecutive wells planned on
    its recently acquired acreage block, with plans to move a rig to its CMR
    8-5 (100% WI) well in Amite County, Mississippi after the Huff 18-7 well

Production:

  oProduction for the quarter increased by 16% sequentially to 7.7 Bcfe, or
    an average of 83,700 Mcfe per day. Oil volumes increased by 28%
    sequentially to 374,000 barrels of oil, or an average of 4,100 barrels of
    oil per day, while gas volumes increased by 11% sequentially to 5.5 Bcf,
    or an average of 59,300 Mcf per day.
  oOil production for the quarter comprised 29% of total production and 70%
    of revenues compared to 23% of total production and 63% of revenues in the
    prior year period. Average realized price per Mcfe of production was $7.38
    ($6.91 including hedges), with an average oil price of $106.11 per barrel
    and average natural gas price of $3.15 per Mcf.

Liquidity and Balance Sheet Improvement:

  oDuring the quarter, the Company entered into separate, privately
    negotiated exchange agreements under which it retired $109.25 million in
    aggregate principal amount of 5% Convertible Senior Notes due 2029 (the
    "2029 Notes"), with an initial put/call date of October 2014, in exchange
    for issuance of a like amount of a new series of 5.0% Convertible Senior
    Notes due 2032 (the "2032 Notes"), with an initial call date of October
    2016 and an initial put date of October 2017. Subsequent to quarter-end
    the Company exchanged an additional $57.4 million of 2029 Notes for $57.0
    million of 2032 Notes, leaving $51.8 million of 2029 Notes outstanding
    with a corresponding amount held in restricted cash.
  oBorrowing base under senior credit facility increased from $243 million to
    $270 million.
  oThe Company exited the quarter with $1.9 million in cash, $109.25 million
    of restricted cash and $142.8 million drawn on its senior bank revolving
    credit facility, with a borrowing base of $243 million. Since the end of
    the quarter, the Company raised net proceeds of $166 million through the
    sale of common stock, received an increase in its borrowing base to $270
    million and exchanged $57.4 million of 2029 Notes (thereby releasing a
    corresponding $57.4 million of restricted cash), providing proforma
    liquidity at quarter-end of $352.4 million. In addition, the Company has
    $51.8 million of restricted cash associated with the remaining 2029 Notes
    for a total of $404.3 million of proforma liquidity and restricted cash.

FINANCIAL RESULTS

Cash Flow

Earnings before interest, taxes, DD&A, non-cash general and administrative
expenses and exploration ("Adjusted EBITDAX") was $34.7 million in the quarter
compared to $48.0 million in the prior year period and $31.5 million in the
prior quarter. 

Discretionary cash flow ("DCF"), defined as net cash provided by operating
activities before changes in working capital was $24.8 million in the quarter
compared to $36.9 million in the prior year period and $20.9 million in the
prior quarter. Net cash provided by operating activities was $5.0 million
compared to $19.6 million for the prior year period.

For the prior year period, both Adjusted EBITDAX and DCF were positively
impacted by a $18.8 million gain on realized derivative settlements compared
to a negative impact of a $3.6 million loss in the current quarter.

(See accompanying tables at the end of this press release that reconcile
Adjusted EBITDAX and DCF, each of which are non-GAAP financial measures, to
their most directly comparable GAAP financial measure.)

NET INCOME

The Company announced a net loss applicable to common stock of $32.8 million
for the quarter or ($0.89) per basic share, versus net income applicable to
common stock of $10.9 million or $0.30 per basic share in the prior year
period. Adjusted net loss applicable to common stock was $19.9 million, which
excludes the impact of the unrealized losses on derivatives not designated as
hedges of $5.1 million, loss on early extinguishment of debt of $4.8 million,
and lease expirations of $2.9 million.

(See accompanying tables at the end of this press release that reconcile
adjusted net loss applicable to common stock, a non-GAAP measure, to its most
directly comparable GAAP financial measure.)

REVENUES

Revenues for the quarter were $57.2 million versus $46.0 million in the prior
year period. Average realized price per unit for the quarter was $7.38 per
Mcfe versus $5.92 per Mcfe in the prior year period. When factoring in the
realized gain or loss on derivatives not designated as hedges, Adjusted
Revenues for the quarter were $53.5 million versus $64.8 million in the prior
year period and average realized price per unit was $6.91 per Mcfe versus
$8.34 per Mcfe in the prior year period.

(See accompanying tables at the end of this press release that reconciles
Adjusted Revenues, a non-GAAP measure, to its most directly comparable GAAP
financial measure.)

OPERATING EXPENSES

Lease operating expense ("LOE") was $7.1 million in the quarter or $0.92 per
Mcfe versus $6.2 million or $0.80 per Mcfe in the prior year period. LOE
included $1.6 million or $0.21 per Mcfe for workovers performed in the
quarter, primarily in the Eagle Ford Shale trend.

Production and other taxes for the quarter were $2.5 million or $0.32 per Mcfe
versus $1.7 million or $0.22 per Mcfe in the prior year period and were driven
by higher oil volumes in the Eagle Ford Shale trend as a percentage of total
volumes, which carry a higher severance tax rate. 

Transportation and processing expense was $2.8 million, or $0.36 per Mcfe in
the quarter versus $3.4 million or $0.44 per Mcfe in the prior year period.

Depreciation, depletion and amortization ("DD&A") expense for the quarter
totaled $33.3 million or $4.33 per Mcfe versus $37.3 million or $4.80 per Mcfe
in the prior year period, with the decline in DD&A expense per unit of
production driven from higher mid-year reserves and lower capital expenditures
per well in the Eagle Ford Shale trend. DD&A expense per unit was $5.18 per
Mcfe for the prior quarter.

Exploration expense was $4.1 million, or $0.53 per Mcfe for the quarter versus
$2.5 million or $0.32 per Mcfe in the prior year period. Approximately $3.4
million or 84% of exploration expense for the quarter was a non-cash expense
for the expiration of undeveloped leasehold and amortization of the Company's
undeveloped leasehold. As part of its ongoing review of capital allocation,
the Company elected not to renew certain expiring leases in its non-core Eagle
Ford Shale trend acreage.

General and Administrative ("G&A") expense was $8.3 million, or $1.08 per Mcfe
in the quarter versus $7.1 million or $0.92 per Mcfe in the prior year period.
G&A expense related to stock based compensation for its employees was $1.7
million or $0.23 per Mcfe versus $1.7 million or $0.22 per Mcfe in the prior
year period.

OPERATING INCOME

Operating income, defined as revenues minus operating expenses, totaled a loss
of $0.9 million for the quarter compared to operating income of $31.9 million
in the prior year period. The prior year period included a gain from the sale
of assets of $44.2 million. Adjusted operating loss which excludes the
realized loss on derivatives not designated as hedges and the loss from
extinguishment of debt was $4.8 million.

(See accompanying tables at the end of this press release that reconcile
adjusted operating loss, a non-GAAP financial measure to its most directly
comparable GAAP financial measure.)

INTEREST EXPENSE

Interest expense for the quarter was $12.7 million or $1.65 per Mcfe versus
$13.3 million or $1.71 per Mcfe in the prior year period. Non-cash interest
expense associated with the Company's long term debt comprised 25% of the
total or $3.2 million ($0.42 per Mcfe).

CRUDE OIL AND NATURAL GAS DERIVATIVES

The Company realized a loss of $3.6 million on its derivatives not designated
as hedges and an unrealized loss of $5.1 million, for a loss on derivatives
not designated as hedges of $8.8 million for the quarter.

CAPITAL EXPENDITURES

Capital expenditures for the quarter were $91.4 million, of which $66.3
million was spent on drilling and completion costs, $22.7 million on the
Company's producing property and leasehold acquisition in the TMS and $2.4
million on other leasehold acquisitions and extensions, facilities and other
expenditures. Capital expenditures for the first nine months of the year were
$204.2 million, of which $174.6 million was spent on drilling and completion
costs, $22.7 million primarily for the TMS acquisition, $5.9 million on
acreage acquisitions and $1.0 million on facilities and other expenditures.

OPERATIONAL UPDATE

For the quarter, the Company spent approximately 32% of the capital in the
Eagle Ford Shale trend, 57% in the TMS and 11% on the completion of previously
drilled Haynesville Shale wells. The Company conducted drilling operations on
8 gross (6 net) wells in the quarter, including 6 gross (4 net) Eagle Ford
Shale trend wells and 2 gross (1.96 net) wells in the TMS. We added 9 gross
(4.87 net) wells to production in the quarter, of which 5 gross (3 net) were
in the Eagle Ford Shale trend, 1 gross (0.90 net) in the TMS and 1 gross (0.50
net) in the Haynesville Shale trend. As of quarter-end, the Company had 8
gross (5.32 net) wells drilled and waiting on completion comprised of 2 gross
(1 net) in theHaynesville Shale trend, 5 gross (3.33 net) in theEagle Ford
Shale trend and 1 gross (0.99 net) in theTMS.

For the year, the Company expects to drill and complete 21 gross (14 net)
wells in the Eagle Ford Shale trend (down 1 gross (0.7 net) wells due to the
reallocation of capital from the Eagle Ford Shale to the TMS), 9 gross (5 net)
wells in the TMS and 13 gross (5.7 net) wells in the Haynesville Shale trend.

OTHER INFORMATION

In this press release, the Company refers to several non-GAAP financial
measures, including Adjusted EBITDAX, DCF, Adjusted revenues, Adjusted
operating income (loss), Adjusted net loss applicable to common stock and Cash
operating margin. Management believes Adjusted EBITDAX, DCF, Adjusted
revenues, Adjusted operating income (loss), Adjusted net loss applicable to
common stock and Cash operating margin are good financial indicators of the
Company's ability to internally generate operating funds. None of DCF,
Adjusted EBITDAX or Cash operating margin, should be considered an alternative
to net cash provided by operating activities, as defined by GAAP. Adjusted
revenues should not be considered an alternative to total revenues, as defined
by GAAP. Adjusted operating income (loss) should not be considered an
alternative to operating income (loss), as defined by GAAP. Adjusted net loss
applicable to common stock should not be considered an alternative to net loss
applicable to common stock, as defined by GAAP. Management believes that all
of these non-GAAP financial measures provide useful information to investors
because they are monitored and used by Company management and widely used by
professional research analysts in the valuation and investment recommendations
of companies within the oil and gas exploration and production industry.

Initial production rates are subject to decline over time and should not be
regarded as reflective of sustained production levels. In particular,
production from horizontal drilling in shale oil and natural gas resource
plays and tight natural gas plays that are stimulated with extensive pressure
fracturing are typically characterized by significant early declines in
production rates.

Unless otherwise stated, oil production volumes include condensate.

Certain statements in this news release regarding future expectations and
plans for future activities may be regarded as "forward looking statements"
within the meaning of the Securities Litigation Reform Act. They are subject
to various risks, such as financial market conditions, changes in commodities
prices and costs of drilling and completion, operating hazards, drilling
risks, and the inherent uncertainties in interpreting engineering data
relating to underground accumulations of oil and gas, as well as other risks
discussed in detail in the Company's Annual Report on Form 10-K for the year
ended December 31, 2012 and other subsequent filings with the Securities and
Exchange Commission. Although the Company believes that the expectations
reflected in such forward looking statements are reasonable, it can give no
assurance that such expectations will prove to be correct.

Goodrich Petroleum is an independent oil and gas exploration and production
company listed on the New York Stock Exchange.

GOODRICH PETROLEUM CORPORATION
SELECTED INCOME AND PRODUCTION DATA
(In Thousands, Except Per Share Amounts)
                             Three Months Ended       Nine Months Ended
                             September 30,            September 30,
                             2013        2012         2013         2012
Volumes
 Natural gas (MMcf)          5,456       5,991        14,506       20,215
 Oil and condensate (MBbls)  374         296          974          766
 MMcfe - Total               7,698       7,764        20,349       24,811
 Mcfe per day                83,676      84,396       74,538       90,553
Total Revenues               $ 57,161   $ 45,960     $ 152,730    $ 132,614
Operating Expenses
 Lease operating expense     7,072       6,218        20,169       21,267
 Production and other taxes  2,462       1,672        7,964        5,752
 Transportation and          2,768       3,410        7,841        11,060
 processing
 Depreciation, depletion     33,320      37,298       102,807      104,138
 and amortization
 Exploration                 4,115       2,523        16,961       6,755
 Impairment                 -           -            -            2,662
 General and administrative  8,294       7,142        25,326       21,753
 Gain on sale of assets      (16)        (44,157)     (59)         (44,229)
 Other                       -           -            (91)         -
Operating income (loss)     (854)       31,854       (28,188)     3,456
Other income (expense)
 Interest expense            (12,679)    (13,314)     (39,079)     (39,316)
 Interest income and other   (1)         2            18           3
 Gain (loss) on derivatives  (8,759)     (6,137)      350          27,331
 not designated as hedges
 Loss from extinguishment    (4,792)     -            (4,792)      -
 of debt
                             (26,231)    (19,449)     (43,503)     (11,982)
Income (loss) before income  (27,085)    12,405       (71,691)     (8,526)
taxes
Income tax                  -           -            -            -
Net income (loss)          (27,085)    12,405       (71,691)     (8,526)
Preferred stock dividends    5,705       1,511        11,173       4,535
Net income (loss)            $ (32,790)  $ 10,894     $ (82,864)  $ (13,061)
applicable to common stock
 Unrealized (gain) loss on
 derivatives not designated  5,112       24,943       (3,762)      28,696
 as hedges
 Exploration - Seismic       -           -            1,047        -
 Lease expirations           2,901       -            11,800       -
 Dry hole cost               69          -            321          -
 Loss from extinguishment    4,792       -            4,792        -
 of debt
 Gain on sale of assets      (16)        (44,157)     (59)         (44,229)
 Other                       -           -            (91)         -
 Impairment                 -           -            -            2,662
Adjusted net loss
applicable to common stock   $ (19,932)  $ (8,320)   $ (68,816)  $ (25,932)
(1)
 Discretionary cash flow
 (see non-GAAP               $ 24,824   $ 36,928     $  62,073   $ 101,627
 reconciliation) (2)
 Adjusted EBITDAX (see
 calculation and non-GAAP    $ 34,655   $ 48,000     $  93,229   $ 133,520
 reconciliation)( 3)
Weighted average common      36,732      36,391       36,706       36,365
shares outstanding - basic
Weighted average common
shares outstanding -         36,732      36,619       36,706       36,365
diluted (4)
Earnings per share
 Net income (loss)           $                      $          $  
 applicable to common stock  (0.89)      $   0.30  (2.26)      (0.36)
 - basic
 Net income (loss)           $                      $          $  
 applicable to common stock  (0.89)      $   0.30  (2.26)      (0.36)
 - diluted
Adjusted earnings per share
 Adjusted net loss           $                      $          $  
 applicable to common stock  (0.54)      $  (0.23)  (1.87)      (0.71)
 - basic (1)
 Adjusted net loss           $                      $          $  
 applicable to common stock  (0.54)      $  (0.23)  (1.87)      (0.71)
 - fully diluted (1)



(1) Adjusted net income (loss) applicable to common stock is defined as net
income (loss) applicable to common stock adjusted to exclude certain charges
or amounts in order to provide users of this financial information with
additional meaningful comparisons between current results and the results of
prior periods. Management presents this measure because (i) it is consistent
with the manner in which the company's performance is measured relative to the
performance of its peers, (ii) this measure is more comparable to earnings
estimates provided by securities analysts, and (iii) charges or amounts
excluded cannot be reasonably estimated and guidance provided by the company
excludes information regarding these types of items. These adjusted amounts
are not a measure of financial performance under GAAP.
(2) Discretionary cash flow is defined as net cash provided by operating
activities before changes in operating assets and liabilities. Management
believes that the non-GAAP measure of operating cash flow is useful as an
indicator of an oil and gas exploration and production company's ability to
internally fund exploration and development activities and to service or incur
additional debt. The company has also included this information because
changes in operating assets and liabilities relate to the timing of cash
receipts and disbursements which the company may not control and may not
relate to the period in which the operating activities occurred. Operating
cash flow should not be considered in isolation or as a substitute for net
cash provided by operating activities prepared in accordance with GAAP.
(3) Adjusted EBITDAX is earnings before interest expense, income tax, DD&A,
exploration expense and impairment of oil and gas properties. In calculating
EBITDAX for this purpose, earnings include realized gains (losses) from
derivatives but exclude unrealized gains (losses) from derivatives. Other
excluded items include Interest income and other, Gain on sale of assets, Gain
on early extinguishment of debt and Other expense.
(4) Fully diluted shares excludesapproximately 10.7 million and 10.4 million
potentially dilutive instruments that were anti-dilutive due to the net loss
applicable to common stock for the three and nine months ended Septmeber 30,
2013, respectively. We report our financial results in accordance with
accounting principles generally accepted in the United States of America
("GAAP"). However, management believes certain non-GAAP performance measures
may provide users of this financial information with additional meaningful
comparisons between current results and the results of our peers and of prior
periods.
GOODRICH PETROLEUM CORPORATION
Per Unit Sales Prices and Costs
                              Three Months Ended        Nine Months Ended
                              September 30              September 30
                              2013         2012         2013         2012
Average sales price per
unit:
    Oil (per Bbl)
     Including
    realized gain and loss    $  96.36    $ 105.63     $ 101.54     $ 105.63
    on oil derivatives
     Excluding
    realized gain and loss    $ 106.11     $  97.43    $ 105.06     $ 100.46
    on oil derivatives
    Natural gas (per Mcf)
     Including
    realized gain on          $          $          $          $  
    natural gas               3.15        5.60        3.42        5.34
    derivatives
     Excluding
    realized gain on          $          $          $          $  
    natural gas               3.15        2.87        3.42        2.76
    derivatives
    Natural gas and oil
    (per Mcfe)
     Including realized   $          $          $          $  
    gain and loss on oil and  6.91        8.34        7.30        7.61
    natural gas derivatives
     Excluding realized   $          $          $          $  
    gain and loss on oil and  7.38        5.92        7.47        5.35
    natural gas derivatives
Costs Per Mcfe
    Lease operating           $          $          $          $  
    expense                   0.92        0.80        0.99        0.86
    Production and other      $          $          $          $  
    taxes                     0.32        0.22        0.39        0.23
    Transportation and        $          $          $          $  
    processing                0.36        0.44        0.39        0.45
    Depreciation,             $          $          $          $  
    depletion and             4.33        4.80        5.05        4.20
    amortization
    Exploration               $          $          $          $  
                              0.53        0.32        0.83        0.27
    Impairment               $        $        $        $  
                                -          -          -        0.11
    General and               $          $          $          $  
    administrative            1.08        0.92        1.24        0.88
    Gain on sale of           $        $           $        $  
    assets/other                -        (5.69)        -        (1.78)
                              $          $          $          $  
                              7.54        1.82        8.89        5.21
Note: Amounts on a per Mcfe basis may not total due to rounding.







GOODRICH PETROLEUM CORPORATION
Selected Cash Flow Data (In Thousands):
Reconciliation of Discretionary Cash Flow and Net Cash Provided by Operating
Activities (unaudited)
                         Three Months Ended           Nine Months Ended
                         September 30,                September 30,
                         2013           2012          2013        2012
Net cash provided by     $           $   
operating activities     4,981         19,643       $ 40,841   $  97,573
(GAAP)
Net changes in working   19,843         17,285        21,232      4,054
capital
Discretionary cash flow  $   24,824   $          $ 62,073   $ 101,627
                                        36,928
Weighted average common
shares outstanding -     36,732         36,391        36,706      36,365
basic
Weighted average common
shares outstanding -     36,732         36,619        36,706      36,365
diluted (4)
Supplemental Balance Sheet Data
                         As of
                         September 30,  December 31,
                         2013           2012
 Cash and cash           $           $    
 equivalents             1,901         1,188
 Long-term debt          625,990        568,671
Reconciliation of Net income (loss) to Adjusted
EBITDAX
                         Three Months Ended           Nine Months Ended
                         September 30,                September 30,
                         2013           2012          2013        2012
 Net income (loss)       $  (27,085)  $          $ (71,691)  $  (8,526)
 (GAAP)                                 12,405
 Exploration expense     4,115          2,523         16,961      6,755
 Depreciation, depletion 33,320         37,298        102,807     104,138
 and amortization
 Impairment              -              -             -           2,662
 Stock compensation      1,737          1,676         5,211       4,711
 expense
 Interest expense       12,679         13,314        39,079      39,316
 Unrealized (gain) loss
 on derivatives not      5,112          24,943        (3,762)     28,696
 designated as hedges
 Loss on early           4,792          -             4,792       -
 extinguishment of debt
 Other excluded items *  (15)           (44,159)      (168)       (44,232)
  Adjusted EBITDAX  $   34,655   $          $ 93,229   $ 133,520
                                        48,000
 * Other excluded items include Interest income and other, Gain on sale of
 assets and Other expense.
Other Information
                         Three Months Ended           Nine Months Ended
                         September 30,                September 30,
                         2013           2012          2013        2012
 Interest expense - cash $           $          $ 29,074   $  29,909
                         9,516         10,178
 Interest expense -      3,163          3,136         10,005      9,407
 noncash
 Total Interest          12,679         13,314        39,079      39,316
 Unrealized (gain) loss
 on derivatives not      5,112          24,943        (3,762)     28,696
 designated as hedges
 Realized (gain) loss on
 derivatives not         3,647          (18,806)      3,412       (56,027)
 designated as hedges
 Total (gain) loss on
 derivatives not         8,759          6,137         (350)       (27,331)
 designated as hedges
 General and
 Administrative expense  6,557          5,466         20,115      17,042
 - cash
 General and
 Administrative expense  1,737          1,676         5,211       4,711
 - noncash
 Total General and       8,294          7,142         25,326      21,753
 Administrative expense







GOODRICH PETROLEUM CORPORATION
Selected Cash Flow Data continued (In Thousands):
Reconciliation of Adjusted Revenues and Total Revenues (unaudited)
                             Three Months Ended        Nine Months Ended
                             September 30,             September 30,
                             2013         2012         2013         2012
Total Revenues (GAAP)        $ 57,161     $ 45,960     $ 152,730    $ 132,614
Realized gain (loss) on
derivatives not designated   (3,647)      18,806       (3,412)      56,027
as hedges
Adjusted Revenues            $ 53,514     $  64,766  $ 149,318    $ 188,641
Reconciliation of Adjusted Operating Income and Operating Income (unaudited)
                             Three Months Ended        Nine Months Ended
                             September 30,             September 30,
                             2013         2012         2013         2012
Operating income (loss)      $   (854)  $ 31,854     $ (28,188)  $  
(GAAP)                                                              3,456
Realized gain (loss) on
derivatives not designated   (3,647)      18,806       (3,412)      56,027
as hedges
Adjusted Operating Income    $ (4,501)   $  50,660  $ (31,600)  $  59,483
(loss)
Calculation of Cash operating margin (unaudited)
                             Three Months Ended        Nine Months Ended
                             September 30,             September 30,
                             2013         2012         2013         2012
Adjusted EBITDAX (see
calculation and non-GAAP     $ 34,655     $ 48,000     $  93,229   $ 133,520
reconciliation) (3)
Adjusted Revenues (see       $ 53,514     $  64,766  $ 149,318    $ 188,641
non-GAAP reconciliation)
Cash operating margin        65%          74%          62%          71%



SOURCE Goodrich Petroleum Corporation

Website: http://www.goodrichpetroleum.com
Contact: Robert C. Turnham, Jr., President or Jan L. Schott, Chief Financial
Officer, (713) 780-9494
 
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