Attached files
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8-K - GOODRICH PETROLEUM CORP | v192397_8-k.htm |
NEWS
from
|
801
Louisiana, Suite 700
Houston,
Texas 77002
Main:
(713) 780-9494
Fax:
(713) 780-9254
Traded: NYSE
(GDP)
|
|
Jan
L. Schott, Sr. VP & Chief Financial Officer
|
FOR IMMEDIATE
RELEASE
GOODRICH
PETROLEUM ANNOUNCES SECOND QUARTER
FINANCIAL
AND OPERATIONAL RESULTS
|
·
|
Net Production Volumes for the
Quarter Increased by 12% Over the Prior Year Period and 4% Sequentially to
an Average of 92,000 Mcfe per
Day
|
|
·
|
Per Unit Lease Operating
Expense (LOE) for the Quarter Decreased by 19% Versus the Prior Year
Period and 16% Sequentially to $0.76 per Mcfe. Total Recurring
Per Unit Operating Expense Reduced by 27% from the Prior Year Period and
13% Sequentially
|
|
·
|
EBITDAX for the Quarter
Increased by 12% Sequentially to $26.9
Million
|
|
·
|
Haynesville Shale (Shelby
Trough)
|
|
o
|
Initial Well in
Nacogdoches/Angelina County area, the SW Henderson 1H, encountered 215
feet of Haynesville Shale and 200 feet of Bossier Shale
Prospective
|
|
o
|
Initial Well in Shelby County,
the R. Dean 1H, encountered 126 feet of Haynesville Shale and 188 feet of
Bossier Shale Prospective
|
|
·
|
Eagle Ford Shale
Play
|
|
o
|
Initial Well Completed in the
Buda Lime Formation with a 24-Hour Initial Production Rate of 530 Barrels
of Oil Equivalent (BOE) Per Day, and a 30-day Average Rate of 435 BOE per
day
|
|
o
|
Initial
Well in the Eagle Ford Shale, the Pan Am B 1H, in Completion
Phase
|
|
·
|
Company Maintains its $255
Million Capital Expenditure Budget, with Current Liquidity of $256
Million
|
Houston, Texas – August 4,
2010. Goodrich Petroleum Corporation (NYSE: GDP) today announced its
financial and operating results for the second quarter ended June 30,
2010.
1
PRODUCTION
Net
production volumes in the quarter increased by 12% to 8.4 billion cubic feet
equivalent ("Bcfe"), or an average of approximately 92,000 Mcfe per day, versus
7.5 Bcfe, or an average of approximately 82,100 Mcfe per day in the prior year
period. Average net daily production volumes for the quarter
increased 4% sequentially. During the second quarter, the Company
completed and added 8 gross (4 net) wells to production compared to 6 gross (2
net) wells during the first quarter.
The
Company expects net daily production volumes to average between 94,000 – 98,000
Mcfe per day in the third quarter of 2010.
NET
INCOME
Net
income applicable to common stock for the quarter was a
loss of $23.1 million, or ($0.64) per share, versus a loss of $36.5 million, or
($1.02) per share for the prior year period. During the quarter, net
income applicable to common stock was positively impacted by both higher
production volumes and lower operating costs relative to the prior year
period. As the Company fully valued its net deferred tax asset at the
end of 2009, the Company is using an effective tax rate of zero for the full
year 2010. Thus, there was no income tax benefit applied to the loss
in the second quarter of 2010.
CASH
FLOW
Earnings
before interest, taxes, DD&A and exploration ("EBITDAX") for the quarter,
decreased by 28% to $26.9 million compared to $37.3 million in the prior year
period (see accompanying table for a reconciliation of EBITDAX, a non-GAAP
measure, to net cash provided by operating activities). EBITDAX was
up 12% sequentially over the first quarter of 2010 on increased production
volumes and lower operating costs.
Discretionary
cash flow ("DCF"), defined as net cash provided by operating activities before
changes in working capital, decreased by 34% to $22.0 million in the quarter
from $33.0 million in the prior year period (see accompanying table for a
reconciliation of DCF, a non-GAAP measure, to net cash provided by operating
activities). DCF increased 114% sequentially from $10.2 million
reported during the first quarter of 2010. Net cash provided by
operating activities was $28.9 million for the quarter, up from $27.1 million in
the prior year period. DCF and net cash provided by operating
activities included a realized gain of $7.7 million on natural gas derivatives
in the second quarter of 2010, compared to the $27.2 million realized gain on
natural gas derivatives in the prior year period.
REVENUES
Total
revenues for the quarter increased by approximately 30% to $34.2 million
compared to $26.3 million for the prior year period. Revenues were
positively impacted by production volume growth of 12% over the prior year
period and higher realized prices of $4.07 per Mcfe versus $3.51 per Mcfe in the
prior year period. Total revenues and average prices received in the
quarter and the prior year period do not include realized gains of $7.7 million
and $27.2 million respectively, received on the Company's settled natural gas
derivatives, none of which were designated as hedges during the second quarters
of 2010 and 2009.
The
Company continued to positively benefit from its hedging program during the
second quarter. Revenue, adjusted for the impact of net realized
gains on natural gas derivatives of $7.7 million, for the second quarter of 2010
was $41.9 million. Taking into account the impact of derivatives, the
Company realized approximately $4.98 per Mcfe of production for the second
quarter of 2010 (see accompanying table titled "Select Operating Data" for
additional disclosure on these adjustments).
2
OPERATING
INCOME
Operating
income (loss) (defined as revenues less lease operating expense, production
taxes, transportation, DD&A, exploration and general and administrative
expenses), was a loss of $12.8 million for the quarter, versus a loss of $53.9
million for the prior year period. The primary reason for the
decrease in operating loss from the prior year period was increased revenue,
coupled with lower lease operating expense, production taxes, transportation
expense, as well as a 31% reduction in per unit DD&A
expense. Operating income (loss) during the prior year period was
negatively impacted by a $23.5 million asset impairment. Operating
income (loss) does not include the realized gain of $7.7 million on natural gas
derivatives in the quarter.
OPERATING
EXPENSES
Lease
operating expense ("LOE") decreased by 9% to $6.3 million in the quarter versus
$7.0 million in the prior year period. LOE decreased by 19% on a per
unit basis to $0.76 per Mcfe in the quarter from $0.94 per Mcfe in the prior
year period. Sequentially, per unit LOE decreased by 16% compared to
$0.91 per Mcfe in the first quarter of 2010. The lower per unit LOE
was primarily driven by reduced salt water disposal and compression costs, as
well as higher per well production volumes and lower costs from the Company's
increasing Haynesville Shale production, which comprised approximately 50% of
the Company's production volumes for the second quarter of 2010.
Production
and other taxes decreased by 63% to $0.4 million in the quarter versus $1.0
million in the prior year period. Production and other taxes decreased by 64% on
a per unit basis to $0.05 per Mcfe in the quarter from $0.14 per Mcfe in the
prior year period. Per unit production and other taxes decreased 58%
sequentially from $0.12 per Mcfe in the first quarter of 2010.
Transportation
expense decreased by 16% to $2.2 million in the quarter versus $2.6 million in
the prior year period. Transportation expense decreased by 26% on a
per unit basis to $0.26 per Mcfe in the quarter from $0.35 per Mcfe in the prior
year period. Per unit transportation expense decreased 16%
sequentially from $0.31 per Mcfe in the first quarter of 2010.
Depreciation,
depletion and amortization ("DD&A") expense decreased to $28.4 million
($3.39 per Mcfe) for the quarter from $36.5 million ($4.89 per Mcfe) from the
prior year period, which represents a 31% decrease on a per unit
basis. Per unit DD&A for the quarter decreased 11% sequentially,
primarily due to a greater amount of production coming from the Company's lower
cost Haynesville Shale properties.
Exploration
expense decreased by 11% to $2.6 million versus $3.0 million in the prior year
period. Exploration expense during the second quarter of 2009
included early termination fees of $1.1 million for two drilling
rigs. The impact of this decrease during the current period was
partially offset by $0.4 million in exploratory seismic costs for the Company's
3-D seismic program in the Angelina River Trend area. Per unit
exploration expense decreased sequentially by 16% to $0.31 per
Mcfe.
General
and administrative ("G&A") expenses totaled $7.0 million for the quarter, or
$0.84 per Mcfe, versus $6.7 million, or $0.90 per Mcfe, during the prior year
period. Per unit G&A decreased by 7% over the prior year period
and 29% sequentially. On a sequential basis, G&A expense was
lower primarily due to additional expenses for bonus payments and the
resignation of an officer during the previous quarter. G&A
expenses for the second quarter of 2010 included $1.5 million of non-cash stock
based compensation costs compared to $1.6 million during the prior year
period.
3
INTEREST
EXPENSE
Interest
expense increased to $9.2 million in the quarter from $5.3 million in the prior
year period, due primarily to additional interest associated with the Company's
5% convertible senior notes issued in September 2009. Of the $9.2
million in interest expense for the quarter, only $4.5 million represents
ongoing cash interest expense. The remaining $4.7 million represents
non-cash charges related to the amortization of debt discounts and deferred
financing costs associated with the Company's convertible notes (as required by
APB 14-1), resulting in a reduction of $55.4 million in long term debt on the
balance sheet as of June 30, 2010.
DERIVATIVES
The
Company recorded a gain on derivatives not designated as hedges during the
second quarter of 2010 of $0.3 million, which includes a realized gain on
natural gas derivatives of $7.7 million and an unrealized loss on natural gas
derivatives of $7.4 million. The second quarter also includes a
realized loss of $0.5 million and an unrealized gain of $0.5 million on the
Company's interest rate swap which ended in April 2010 (see accompanying table
titled "Supplementary Information" for additional disclosure on these
adjustments).
LIQUIDITY
The
Company exited the quarter with $56.5 million in cash and short term investments
and $200 million of available borrowing capacity under its bank credit
facility. The Company believes that its strong liquidity position of
$256 million, along with cash flow from operations, provides ample liquidity to
fund the Company's development plans through 2011.
CAPITAL
EXPENDITURES
Capital
expenditures for the quarter totaled $80.0 million, compared to $65.3 million in
the prior year period. Of the $80.0 million in capital expenditures
for the quarter, approximately $56.6 million, or 71% of the total was associated
with the drilling and/or completion of 22 gross (12 net)
wells. Additionally, the Company spent approximately $21.5 million on
leasehold acquisitions (with approximately $20.0 million spent in the Eagle Ford
Shale play) and $1.9 million on recompletions and other capital
expenditures.
The
Company conducted drilling operations on 15 gross (9 net) wells in the quarter,
with 8 gross (4 net) wells added to production, with a 100% success
rate. As of June 30, 2010, 14 gross (7 net) wells were cased and
waiting on completion.
During
the quarter, the Company had three operated and four non-operated rigs working
in the area of East Texas and North Louisiana. For the remainder of
the year, the Company anticipates a total of three operated rigs running, with
two in East Texas and the North Louisiana region and one in the Eagle Ford Shale
oil play in South Texas, along with two non-operated rigs working in North
Louisiana.
4
OTHER – LITIGATION
UPDATE
In the
first quarter of 2010, the Company accrued $8.5 million in expense related to a
judgment in a case filed in Louisiana state court in Caddo Parish,
Louisiana. The case involves a dispute over the interpretation of a
"most favored nations" provision and a separate oil and gas lease taken by a
sub-lessee of the Company. Subsequent to the end of the second
quarter, the Company and the sub-lessee executed an agreement whereby the
sub-lessee agreed to reimburse the Company for one-half of any sums for which
the Company may be cast in judgment in this lawsuit in any final non-appealable
judgment, and further agreed to reimburse the Company for 50% of the cash bond
posted on appeal. The effect will be a $4.25 million credit to the
Company in the third quarter of 2010 for the previously taken expense during the
first quarter of 2010.
OPERATIONAL
UPDATE
The
Company conducted drilling operations on 15 gross (9 net) wells in the quarter,
with 8 gross (4 net) wells added to production, with a 100% success
rate. As of June 30, 2010, the Company's backlog of net wells drilled
and waiting on completion increased sequentially to 14 gross (7 net)
wells.
Haynesville
Shale - Shelby Trough
The
Company has drilled and logged its SW Henderson 1H (100% WI) well in Angelina
County, Texas, with an estimated 215 feet of Haynesville Shale and 200 feet of
Bossier Shale prospective in the well. The Company is currently
drilling the lateral and is anticipating completing the well in early
September.
The
Company has also drilled and logged its R Dean 1H (80% WI) well in Shelby
County, Texas, with an estimated 126 feet of Haynesville Shale and 188 feet of
Bossier Shale prospective. The Company has reached total depth on the
lateral in the Haynesville Shale and is currently moving the rig to drill its R
Dean 2H (80% WI), which it anticipates will be its initial Bossier Shale
completion.
South
Texas Eagle Ford Shale Oil Play
As
previously announced, the Company has entered into agreements to acquire
approximately 50,000 gross (35,000 net) acres in the oil window of the Eagle
Ford Shale play in LaSalle and Frio Counties, Texas. Currently, the
Company estimates its acreage position in the play at approximately 37,500 net
acres. The Company has drilled or participated in the drilling of the
Goodrich Petroleum Company – Pan Am B 1H, formerly known as the Francis Shiner
B-1 (80% WI) and the Blackbrush Oil & Gas – Pals Ranch 9H (50% WI) targeting
the Buda Lime formation, which sits directly below the Eagle Ford
Shale. The Pan Am B-1H, which is a horizontal Eagle Ford Shale well
with a lateral length of approximately 4,700 feet, is currently in completion
phase. The Pals Ranch 9H was completed without stimulation as an
open-hole completion with an initial 24-hour production rate of 530 BOE (77%
oil) and a 30-day average rate of 435 BOE/day. By year-end, the
Company expects to have conducted drilling operations on approximately four
gross wells targeting the Eagle Ford Shale and three gross wells targeting
the Buda Lime formation.
South
Henderson: Cotton Valley Taylor Sand Play
The
Company has drilled and completed its Pone 6H horizontal well in the Taylor
Sand. The well was drilled with a lateral of approximately 4,200',
however, the well experienced numerous mechanical problems during the completion
phase and as a result, the well is currently only producing from approximately
19% of the lateral. The well is in early stages of flow back at a
current rate of 1,000 Mcf per day on a 21/64 inch choke with 665
psi. The Company's second horizontal Cotton Valley Taylor Sand well
in the South Henderson Field, the Goodrich Petroleum Company – Craig 2H, is
expected to spud in late August 2010.
5
MANAGEMENT
COMMENTS
Commenting
on the second quarter results, Walter G. "Gil" Goodrich, Vice-Chairman and CEO
stated, “During the second quarter, we made tremendous progress on almost every
front. Our initial delineation efforts in both the Eagle Ford Shale
and Shelby Trough are extremely encouraging and we anticipate positive follow-on
results in the coming months. Our core Haynesville Shale activities
again delivered outstanding results, which lead to very strong production growth
in the quarter. In addition, we had an exceptional quarter on
reducing per unit operating costs across the board, led by a 16% sequential
decline in lease operating expense and an 11% decline in DD&A due primarily
to our attractive finding cost in the Haynesville Shale. Even in the
current environment, we are confident we will deliver solid growth and
additional asset value creation in the second half of the year.”
OTHER
INFORMATION
In this
press release, the Company refers to two non-GAAP financial measures, EBITDAX
and discretionary cash flow. Management believes
that each of these measures is a good financial indicator of the Company's
ability to internally generate operating funds. Management also
believes that these non-GAAP financial measures of cash flow provide useful
information to investors because they are widely used by professional research
analysts in the valuation and investment recommendations of companies within the
oil and natural gas exploration and production industry. Neither
discretionary cash flow nor EBITDAX should be considered an alternative to net
cash provided by operating activities, as defined by GAAP.
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 and uncertainties, such as availability of drilling rigs and
completion crews and equipment, financial market conditions, 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 and other
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.
Initial
production rates stated in this release are expected to differ substantially
from longer term average production rates. Forward looking estimates
of production growth assume drilling results comparable to recent prior periods,
which may not be realized. The Company is commencing its initial
operations in the Eagle Ford Shale and the success of its drilling and
completion strategy is subject to more uncertainty relative to areas where the
Company has already established drilling and production history.
Goodrich
Petroleum Corporation is an independent oil and gas exploration and production
company listed on the New York Stock Exchange. Substantially all of
its properties are located in Louisiana and Texas.
6
GOODRICH
PETROLEUM CORPORATION
Selected
Income Data
(In
Thousands, Except Per Share Amounts)
(Unaudited)
Three
Months Ended
|
Six
Months Ended
|
|||||||||||||||
June
30,
|
June
30,
|
|||||||||||||||
2010
|
2009
|
2010
|
2009
|
|||||||||||||
Total
Revenues
|
$ | 34,162 | $ | 26,263 | $ | 74,617 | $ | 54,724 | ||||||||
Operating
Expenses
|
||||||||||||||||
Lease
operating expense
|
6,329 | 6,984 | 13,561 | 15,980 | ||||||||||||
Production
and other taxes
|
390 | 1,049 | 1,353 | 2,537 | ||||||||||||
Transportation
|
2,189 | 2,591 | 4,642 | 5,179 | ||||||||||||
Depreciation,
depletion and amortization
|
28,403 | 36,537 | 58,616 | 70,195 | ||||||||||||
Exploration
|
2,627 | 2,959 | 5,606 | 5,179 | ||||||||||||
Impairment
of oil and gas properties
|
- | 23,490 | - | 23,490 | ||||||||||||
General
and administrative
|
7,001 | 6,713 | 16,447 | 13,770 | ||||||||||||
Gain
on sale of assets
|
- | (113 | ) | - | (113 | ) | ||||||||||
Other
|
- | - | 8,500 | - | ||||||||||||
Operating
loss
|
(12,777 | ) | (53,947 | ) | (34,108 | ) | (81,493 | ) | ||||||||
Other
income (expense)
|
||||||||||||||||
Interest
expense
|
(9,195 | ) | (5,298 | ) | (18,315 | ) | (10,506 | ) | ||||||||
Interest
income and other
|
53 | 202 | 106 | 448 | ||||||||||||
Gain
on derivatives not designated as hedges
|
320 | 2,556 | 35,049 | 39,562 | ||||||||||||
(8,822 | ) | (2,540 | ) | 16,840 | 29,504 | |||||||||||
Loss
before income taxes
|
(21,599 | ) | (56,487 | ) | (17,268 | ) | (51,989 | ) | ||||||||
Income
tax benefit
|
- | 21,505 | - | 20,151 | ||||||||||||
Net
loss
|
(21,599 | ) | (34,982 | ) | (17,268 | ) | (31,838 | ) | ||||||||
Preferred
stock dividends
|
1,512 | 1,512 | 3,024 | 3,024 | ||||||||||||
Net
loss applicable to common stock
|
$ | (23,111 | ) | $ | (36,494 | ) | $ | (20,292 | ) | $ | (34,862 | ) | ||||
Per
Common Share
|
||||||||||||||||
Net
loss applicable to common stock - basic
|
$ | (0.64 | ) | $ | (1.02 | ) | $ | (0.57 | ) | $ | (0.97 | ) | ||||
Net
loss applicable to common stock - diluted
|
$ | (0.64 | ) | $ | (1.02 | ) | $ | (0.57 | ) | $ | (0.97 | ) | ||||
Weighted
average common shares outstanding - basic
|
35,918 | 35,937 | 35,888 | 35,953 | ||||||||||||
Weighted
average common shares outstanding - diluted
|
35,918 | 35,937 | 35,888 | 35,953 |
7
GOODRICH
PETROLEUM CORPORATION
Selected
Cash Flow Data (In Thousands):
(Unaudited)
Three
Months Ended
|
Six
Months Ended
|
|||||||||||||||
June
30,
|
June
30,
|
|||||||||||||||
2010
|
2009
|
2010
|
2009
|
|||||||||||||
Calculation
of EBITDAX:
|
||||||||||||||||
Revenue
|
$ | 34,162 | $ | 26,263 | $ | 74,617 | $ | 54,724 | ||||||||
Lease
operating expense
|
(6,329 | ) | (6,984 | ) | (13,561 | ) | (15,980 | ) | ||||||||
Production
and other taxes
|
(390 | ) | (1,049 | ) | (1,353 | ) | (2,537 | ) | ||||||||
Transportation
|
(2,189 | ) | (2,591 | ) | (4,642 | ) | (5,179 | ) | ||||||||
G&A
- cash portion only
|
(5,521 | ) | (5,141 | ) | (12,458 | ) | (10,567 | ) | ||||||||
Realized
gain on derivatives not designated as hedges
|
7,135 | 26,801 | 8,220 | 47,827 | ||||||||||||
EBITDAX
|
$ | 26,868 | $ | 37,299 | $ | 50,823 | $ | 68,288 | ||||||||
Reconciliation
of EBITDAX to Net Cash Provided by Operating Activities:
|
||||||||||||||||
EBITDAX
|
$ | 26,868 | $ | 37,299 | $ | 50,823 | $ | 68,288 | ||||||||
Exploration
|
(2,627 | ) | (2,959 | ) | (5,606 | ) | (5,179 | ) | ||||||||
Prospect
amortization
|
1,585 | 1,377 | 3,190 | 2,901 | ||||||||||||
Exploration
non-cash
|
530 | - | 1,005 | 101 | ||||||||||||
Interest
expense
|
(4,449 | ) | (2,924 | ) | (8,820 | ) | (5,885 | ) | ||||||||
Interest
income and other
|
53 | 202 | 106 | 448 | ||||||||||||
Other
expense
|
- | - | (8,500 | ) | - | |||||||||||
Current
Income taxes
|
- | 31 | - | 35 | ||||||||||||
Net
changes in working capital
|
6,926 | (5,910 | ) | 15,455 | 2,664 | |||||||||||
Net
cash provided by operating activities (GAAP)
|
$ | 28,886 | $ | 27,116 | $ | 47,653 | $ | 63,373 | ||||||||
Reconciliation
of Discretionary Cash Flow to Net Cash Provided by Operating
Activities:
|
||||||||||||||||
Discretionary
cash flow
|
$ | 21,960 | $ | 33,026 | $ | 32,198 | $ | 60,709 | ||||||||
Net
changes in working capital
|
6,926 | (5,910 | ) | 15,455 | 2,664 | |||||||||||
Net
cash provided by operating activities (GAAP)
|
$ | 28,886 | $ | 27,116 | $ | 47,653 | $ | 63,373 | ||||||||
Selected
Operating Data:
|
||||||||||||||||
Three
Months Ended
|
Six
Months Ended
|
|||||||||||||||
June
30,
|
June
30,
|
|||||||||||||||
2010
|
2009
|
2010
|
2009
|
|||||||||||||
Production:
|
||||||||||||||||
Natural
gas (MMcf)
|
8,187 | 7,223 | 15,967 | 13,768 | ||||||||||||
Oil
and condensate (MBbls)
|
31 | 41 | 64 | 86 | ||||||||||||
Total
(Mmcfe)
|
8,373 | 7,469 | 16,351 | 14,287 | ||||||||||||
Average
realized prices per unit:
|
||||||||||||||||
Oil
(per Bbl)
|
$ | 73.21 | $ | 52.98 | $ | 74.64 | $ | 42.75 | ||||||||
Natural
gas (per Mcf):
|
||||||||||||||||
Including
realized gain on natural gas derivatives
|
4.82 | 7.09 | 4.95 | 7.21 | ||||||||||||
Excluding
realized gain on natural gas derivatives
|
3.88 | 3.33 | 4.36 | 3.70 | ||||||||||||
Natural
gas and oil (per Mcfe):
|
||||||||||||||||
Including
realized gain on natural gas derivatives
|
4.98 | 7.15 | 5.13 | 7.21 | ||||||||||||
Excluding
realized gain on natural gas derivatives
|
4.07 | 3.51 | 4.55 | 3.83 | ||||||||||||
Expenses
per Mcfe:
|
||||||||||||||||
Lease
operating expense
|
$ | 0.76 | $ | 0.94 | $ | 0.83 | $ | 1.12 | ||||||||
Production
and other taxes
|
0.05 | 0.14 | 0.08 | 0.18 | ||||||||||||
Transportation
|
0.26 | 0.35 | 0.28 | 0.36 | ||||||||||||
DD&A
|
3.39 | 4.89 | 3.58 | 4.91 | ||||||||||||
Exploration
|
0.31 | 0.40 | 0.34 | 0.36 | ||||||||||||
Impairment
of oil and gas properties
|
- | 3.14 | - | 1.64 | ||||||||||||
General
and administrative
|
0.84 | 0.90 | 1.01 | 0.96 | ||||||||||||
Gain
on sale of assets
|
- | (0.02 | ) | - | (0.01 | ) | ||||||||||
Other
|
- | - | 0.52 | - |
8
GOODRICH
PETROLEUM CORPORATION
Supplementary
Data (In Thousands, Except Per Share Amounts):
(Unaudited)
Supplementary
information:
|
||||||||||||||||
|
Three
Months Ended
|
Six
Months Ended
|
||||||||||||||
|
June
30,
|
June
30,
|
||||||||||||||
|
2010
|
2009
|
2010
|
2009
|
||||||||||||
|
||||||||||||||||
Natural
gas derivatives not designated as hedges:
|
||||||||||||||||
Realized
gain
|
$ | 7,686 | $ | 27,189 | $ | 9,329 | $ | 48,324 | ||||||||
Unrealized
gain (loss)
|
(7,363 | ) | (24,380 | ) | 25,742 | (8,370 | ) | |||||||||
Interest
rate derivatives not designated as hedges:
|
||||||||||||||||
Realized
loss
|
$ | (551 | ) | $ | (388 | ) | $ | (1,109 | ) | $ | (497 | ) | ||||
Unrealized
gain
|
548 | 135 | 1,087 | 105 | ||||||||||||
Gain
on derivatives not designated as hedges (GAAP)
|
$ | 320 | $ | 2,556 | $ | 35,049 | $ | 39,562 | ||||||||
|
||||||||||||||||
Cash
interest expense
|
$ | 4,449 | $ | 2,924 | $ | 8,820 | $ | 5,885 | ||||||||
Amortization
of debt discount and finance costs
|
4,746 | 2,374 | 9,495 | 4,621 | ||||||||||||
Interest
expense (GAAP)
|
$ | 9,195 | $ | 5,298 | $ | 18,315 | $ | 10,506 | ||||||||
|
||||||||||||||||
Cash
general and administrative expense
|
$ | 5,521 | $ | 5,141 | $ | 12,458 | $ | 10,567 | ||||||||
Stock
based compensation (non-cash)
|
1,480 | 1,572 | 3,989 | 3,203 | ||||||||||||
General
and administrative expense (GAAP)
|
$ | 7,001 | $ | 6,713 | $ | 16,447 | $ | 13,770 | ||||||||
|
||||||||||||||||
Net
income (loss) adjusted for non-recurring items below
|
$ | (15,856 | ) | $ | 11,128 | $ | (35,999 | ) | $ | (3,220 | ) | |||||
Unrealized
gain (loss) on derivatives not designated as hedges
|
(6,815 | ) | (24,245 | ) | 26,829 | (8,265 | ) | |||||||||
Other
- Hoover Tree Farm ruling litigation
|
- | - | (8,500 | ) | - | |||||||||||
G&A
- resignation of an officer of the company
|
- | - | (867 | ) | - | |||||||||||
G&A
- additional 2009 bonus paid in March 2010
|
- | - | (875 | ) | - | |||||||||||
Exploration
- Angelina River Trend 3-D seismic
|
(440 | ) | - | (880 | ) | - | ||||||||||
Gain
on sale of assets
|
- | 113 | - | 113 | ||||||||||||
Impairment
of oil and gas properties
|
- | (23,490 | ) | - | (23,490 | ) | ||||||||||
Net
loss applicable to common stock (GAAP)
|
$ | (23,111 | ) | $ | (36,494 | ) | $ | (20,292 | ) | $ | (34,862 | ) | ||||
|
||||||||||||||||
Per
Common Share (basic):
|
||||||||||||||||
Net
loss adjusted for non-recurring items below
|
$ | (0.44 | ) | $ | 0.31 | $ | (1.00 | ) | $ | (0.09 | ) | |||||
Unrealized
gain (loss) on derivatives not designated as hedges
|
(0.19 | ) | (0.68 | ) | 0.74 | (0.23 | ) | |||||||||
Other
- Hoover Tree Farm litigation
|
- | - | (0.25 | ) | - | |||||||||||
G&A
- resignation of an officer of the company
|
- | - | (0.02 | ) | - | |||||||||||
G&A
- additional 2009 bonus paid in March 2010
|
- | - | (0.02 | ) | - | |||||||||||
Exploration
- Angelina River Trend 3-D seismic
|
(0.01 | ) | - | (0.02 | ) | - | ||||||||||
Gain
on sale of assets
|
- | - | - | - | ||||||||||||
Impairment
of oil and gas properties
|
- | (0.65 | ) | - | (0.65 | ) | ||||||||||
Net
loss applicable to common stock (GAAP)
|
$ | (0.64 | ) | $ | (1.02 | ) | $ | (0.57 | ) | $ | (0.97 | ) | ||||
|
||||||||||||||||
Per
Common Share (diluted):
|
||||||||||||||||
Net
income adjusted for non-recurring items below
|
$ | (0.44 | ) | $ | 0.31 | $ | (1.00 | ) | $ | (0.09 | ) | |||||
Unrealized
gain (loss) on derivatives not designated as hedges
|
(0.19 | ) | (0.68 | ) | 0.74 | (0.23 | ) | |||||||||
Other
- Hoover Tree Farm litigation
|
- | - | (0.25 | ) | - | |||||||||||
G&A
- resignation of an officer of the company
|
- | - | (0.02 | ) | - | |||||||||||
G&A
- additional 2009 bonus paid in March 2010
|
- | - | (0.02 | ) | - | |||||||||||
Exploration
- Angelina River Trend 3-D seismic
|
(0.01 | ) | - | (0.02 | ) | - | ||||||||||
Gain
on sale of assets
|
- | - | - | - | ||||||||||||
Impairment
of oil and gas properties
|
- | (0.65 | ) | - | (0.65 | ) | ||||||||||
Net
income applicable to common stock (GAAP)
|
$ | (0.64 | ) | $ | (1.02 | ) | $ | (0.57 | ) | $ | (0.97 | ) | ||||
|
||||||||||||||||
Operating
expense adjusted for non-recurring items below
|
$ | 46,499 | $ | 56,833 | $ | 97,603 | $ | 112,840 | ||||||||
Other
- Hoover Tree Farm ruling litigation
|
- | - | 8,500 | - | ||||||||||||
G&A
- resignation of an officer of the company
|
- | - | 867 | - | ||||||||||||
G&A
- additional 2009 bonus paid in March 2010
|
- | - | 875 | - | ||||||||||||
Exploration
- Angelina River Trend 3-D seismic
|
440 | - | 880 | - | ||||||||||||
Gain
on sale of assets
|
- | (113 | ) | - | (113 | ) | ||||||||||
Impairment
of oil and gas properties
|
- | 23,490 | - | 23,490 | ||||||||||||
Operating
expense (GAAP)
|
$ | 46,939 | $ | 80,210 | $ | 108,725 | $ | 136,217 | ||||||||
|
||||||||||||||||
Operating
loss adjusted for non-recurring items below
|
$ | (12,337 | ) | $ | (30,570 | ) | $ | (22,986 | ) | $ | (58,116 | ) | ||||
Other
- Hoover Tree Farm ruling litigation
|
- | - | (8,500 | ) | - | |||||||||||
G&A
- resignation of an officer of the company
|
- | - | (867 | ) | - | |||||||||||
G&A
- additional 2009 bonus paid in March 2010
|
- | - | (875 | ) | - | |||||||||||
Exploration
- Angelina River Trend 3-D seismic
|
(440 | ) | - | (880 | ) | - | ||||||||||
Gain
on sale of assets
|
- | 113 | - | 113 | ||||||||||||
Impairment
of oil and gas properties
|
- | (23,490 | ) | - | (23,490 | ) | ||||||||||
Operating
loss (GAAP)
|
$ | (12,777 | ) | $ | (53,947 | ) | $ | (34,108 | ) | $ | (81,493 | ) |
9