Goodrich Petroleum Announces 2013 Capital Expenditure Budget, Guidance And Operational Update

  Goodrich Petroleum Announces 2013 Capital Expenditure Budget, Guidance And
                              Operational Update

PR Newswire

HOUSTON, Jan. 3, 2013

HOUSTON, Jan. 3, 2013 /PRNewswire/ --Goodrich Petroleum Corporation (NYSE:
GDP) today announced its preliminary capital expenditure budget for 2013,
along with production and cash flow guidance for the year.


The Company today announced a preliminary capital expenditure budget for 2013
of $175 – 200 million, which includes $160 – 185 million in drilling and
completion expenditures and $15 million allocated to leasehold and
infrastructure expenses. The Company anticipates drilling and/or completion
operations on 44 – 48 gross (24 – 26 net) wells for the year, with
approximately 85% of the anticipated drilling and completion capital
expenditures allocated to oil directed activity.

The Company's 2013 capital expenditure budget is designed to allow for
flexibility to allocate capital within the range of the total capital
expenditures in either the Eagle Ford Shale or the Tuscaloosa Marine Shale
("TMS"). Oil directed activity will be concentrated in the Eagle Ford Shale
trend with $115 – 137 million allocated to 24 – 28 gross (16 – 19 net) wells,
and the TMS trend, with $25 – 50 million allocated to 6 – 10 gross (2 – 4 net)
wells. The gas directed capital expenditure budget is $22 million, which is
allocated to the completion of 13 gross (6 net) Haynesville Shale wells that
have been previously drilled.

Capital expenditures for 2012 are expected to be approximately $250 million,
which is consistent with the Company's previously disclosed budget.


The Company estimates oil volumes to grow by 40 – 60% in 2013 versus 2012,
natural gas volumes to grow by 10 – 15% from the previously issued guidance
for the fourth quarter of 2012 to the fourth quarter of 2013, yet be down year
over year by approximately 10%, and overall production on a Mcfe basis is
expected to be relatively flat year over year. Oil volumes are estimated to
comprise approximately 30 – 35% of total production and 65 – 70% of revenue
for the year.


The Company recently added crude oil swaps for 2013 on 2,000 barrels of oil
per day and currently has 3,500 barrels of oil per day, or approximately 70%
of 2013 estimated volumes hedged at NYMEX West Texas Intermediate ("WTI")
price of approximately $94.50 per barrel. Current oil price differential to
WTI is approximately + $12.00 per barrel for the Company's Eagle Ford Shale
production and +$18.00 per barrel in the TMS. The Company is currently
unhedged on natural gas.


Earnings before interest, taxes, DD&A, non-cash general and administrative
expenses and exploration ("Adjusted EBITDAX") is expected to be $165 – $185
million for the year factoring in the Company's production forecasts, hedges
and based on NYMEX pricing of $90.00 per barrel of oil (WTI) and $3.50 per
Mcf of natural gas. Commodity price differentials were estimated at a $10.00
per barrel premium to WTI on oil and Henry Hub pricing less $0.24 per Mcf on
natural gas.

Discretionary cash flow ("DCF"), defined as net cash provided by operating
activities before changes in working capital is expected to be $125 – $140
million under the same production, hedging and commodity price assumptions.

Adjusted EBITDAX and DCF are non-GAAP financial measures. Please see "Other
Information" below.


The Company exited 2012 with $95 million drawn on its senior credit facility
with a current borrowing base of $210 million, providing approximately $115
million of liquidity at year-end. The Company expects its borrowing base will
increase incrementally in 2013 due to continued oil volume production and
reserve growth and assuming no change in the bank group's commodity price
assumptions, with its first redetermination due in March. Based on estimated
capital expenditures and cash flow for 2013, the Company expects to finance
approximately 70% of its capital expenditure budget with cash flow from
operations and the balance with borrowings under its senior credit facility.
The Company may seek additional liquidity through the joint venture of its
TMS acreage or other monetizations, and if completed, will consider
acceleration of its Eagle Ford and/or TMS drilling program in the second half
of the year.


Eagle Ford Shale

Average drilling days per well deceased by 40 percent sequentially in the
quarter to 11 days for an average 6,000 foot lateral. Gross well costs for
2013 are projected to average $7.0 – $7.5 million for an average 6,000 foot
lateral, which incorporates the lower well costs due to the faster drilling
and cycle times achieved in the second half of 2012, as well as the reduced
pressure pumping agreements in place for 2013. The Company currently plans to
spud its initial Pearsall Shale test well in the first quarter.

Tuscaloosa Marine Shale ("TMS")

The Company was unable to repair the parted casing connection in the Denkmann
33H-1 (75% WI) and is currently working on plans to sidetrack the well at a
later date. The Company has drilled its Crosby 12H-1 (50% WI) and is
scheduled to commence fracking operations in January. The Crosby 12H-1 is an
approximate 7,000 foot lateral with 23 planned frac stages. The Company has
participated in the drilling of two non-operated wells, the Ash 31H-1 (12% WI)
and Ash 31H-2 (12% WI), which are also expected to be fracked during January.
The Ash 31H-1 is a 6,500 foot lateral and the Ash 31H-2 is currently drilling
with a planned 7,000 foot lateral. Current plans for 2013 include
participating as a non-operator in 4 – 6 gross (1.0 – 1.25 net) wells and
drilling 2 – 4 gross (1.0 – 2.75 net) operated wells, with the potential to
accelerate in the second half of the year.

Goodrich's Chief Executive Officer, Walter G. "Gil" Goodrich stated, "We are
pleased to announce our board approved capital expenditure budget and
preliminary plans for 2013. The budget and planning is tailored to achieve a
number of key objectives, including: (a) the continuation of our transition to
a more balanced production and reserve mix between crude oil and natural gas;
(b), maintain ample liquidity; (c), continue a high level of activity in the
Eagle Ford Shale trend; (d), initiate development of the Pearsall Shale; and
(e) further develop and define the economic value of our position in the
Tuscaloosa Marine Shale trend.

Our preliminary plans will allow us to achieve robust growth in oil production
volumes over 2012, which will equate to approximately two-thirds of our
projected revenue in 2013. The crude oil hedges we recently added for 2013
provide us price protection on approximately seventy percent of estimated
crude oil production. Despite being currently unhedged on natural gas
volumes, the high percentage of 2013 revenue and cash flow expected to be
generated from crude oil production, as well as our crude oil hedges, provides
solid overall cash flow protection. Based on our current production and
commodity price forecasts, we anticipate approximately seventy percent of our
capital expenditure budget will be funded with cash flow from operations.
This high level of cash flow to capex coverage should in turn allow us to
maintain ample liquidity during 2013 as we execute a number of strategic
corporate objectives.

We exited 2012 with $95 million outstanding under our senior credit facility,
down from $99 million outstanding at the end of the third quarter providing us
with liquidity of approximately $115 million as we enter 2013. Assuming no
changes in our bank group's commodity price assumptions, our continued crude
oil production growth should provide incremental improvement in the amount of
our borrowing base during 2013.

While we are certainly disappointed that we were not able to repair the parted
casing on the Denkmann 33H-1 in the TMS, we are currently working on plans to
sidetrack around the obstruction and re-drill the lateral portion of the well.
In addition, we are pleased with the drilling of the lateral in the Crosby
12H-1 well, have set and cemented production casing, and are anticipating
completion results in the coming weeks in addition to our two non-operated Ash
wells. We also expect a number of additional completions and data points in
the next couple of months which we believe will incrementally assist in
demonstrating the economic viability of this emerging oil play."


In this press release, the Company refers to several non-GAAP financial
measures, including Adjusted EBITDAX, DCF and drilling and completion capital
expenditures. Management believes Adjusted EBITDAX and Discretionary cash
flow are good financial indicators of the Company's ability to internally
generate operating funds, while drilling and completion capital expenditures
are a useful measure of the Company's annual drilling expenditures. Neither
discretionary cash flow, nor Adjusted EBITDAX, should be considered an
alternative to net cash provided by operating activities, as defined by GAAP.
Nor should drilling and completion capital expenditures be considered an
alternative to costs incurred in oil and gas property acquisition,
exploration, and development activities, 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.

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, 2011 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.

SOURCE Goodrich Petroleum Corporation

Contact: Robert C. Turnham, Jr. , President, or Jan L. Schott, Chief Financial
Officer, or Daniel E. Jenkins, Director of Investor Relations, +1-713-780-9494
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