Net Reserves
    
    Future Net Revenue (M$)Oil
    
    NGL
    
    Gas
    
    
    
    
    
    Present WorthCategory
    
    (MBBL)
    
    (MBBL)
    
    (MMCF)
    
    Total
    
    at 10%Proved Developed Producing
    
    
    28,870.8
    
    
    
    0.4
    
    
    
    944.0
    
    
    
    571,725.1
    
    
    
    339,233.4Proved Developed Non-Producing
    
    
    1,577.6
    
    
    
    0.0
    
    
    
    212.0
    
    
    
    39,199.3
    
    
    
    19,598.5Proved Undeveloped
    
    
    3,321.1
    
    
    
    0.0
    
    
    
    0.0
    
    
    
    64,540.9
    
    
    
    28,569.0Total Proved
    
    
    33,769.5
    
    
    
    0.4
    
    
    
    1,156.0
    
    
    
    675,465.2
    
    
    
    387,401.0
 Totals may not add because of rounding.




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Sincerely,NETHERLAND, SEWELL & ASSOCIATES, INC.Texas Registered Engineering Firm F-002699/s/ C.H. (Scott) Rees IIIBy:C.H. (Scott) Rees III, P.E.Chairman and Chief Executive Officer/s/ J. Carter Henson, Jr.
    
    
    
    /s/ Mike K. NortonBy:
    
    
    
    By:J. Carter Henson, Jr., P.E. 73964
    
    
    
    Mike K. Norton, P.G. 441Senior Vice President
    
    
    
    Senior Vice PresidentDate Signed: January 28, 2010
    
    Date Signed: January 28, 2010




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Acquisition of properties.
 Analogous reservoir
 (i)
    
    Same geological formation (but not necessarily in pressure communication with the
reservoir of interest);(ii)
    
    Same environment of deposition;(iii)
    
    Similar geological structure; and(iv)
    
    Same drive mechanism.
 Instruction to paragraph (a)(2)
 Bitumen
 Condensate
 Deterministic estimate
 Developed oil and gas reserves
 (i)
    
    Through existing wells with existing equipment and operating methods or in which
the cost of the required equipment is relatively minor compared to the cost of a new
well; and(ii)
    
    Through installed extraction equipment and infrastructure operational at the time
of the reserves estimate if the extraction is by means not involving a well.
  Supplemental definitions from the 2007 Petroleum Resources Management System:
 Developed Producing Reserves  Developed Producing Reserves are expected to be recovered
from completion intervals that are open and producing at the time of the estimate.   Improved
recovery reserves are considered producing only after the improved recovery project is in
operation.
 Developed Non-Producing Reserves  Developed Non-Producing Reserves include shut-in and
behind-pipe Reserves.   Shut-in Reserves are expected to be recovered from (1) completion
intervals which are open at the time of the estimate but which have not yet started
producing, (2) wells which were shut-in for market conditions or pipeline connections, or
(3) wells not capable of production for mechanical reasons.   Behind-pipe Reserves are
expected to be recovered from zones in existing wells which will require additional
completion work or future recompletion prior to start of production.   In all cases,
production can be initiated or restored with relatively low expenditure compared to the cost
of drilling a new well.
 Development costs.
 (i)
    
    Gain access to and prepare well locations for drilling, including surveying well
locations for the purpose of determining specific development drilling sites, clearing
ground, draining, road building, and relocating public roads, gas lines, and power
lines, to the extent necessary in developing the proved reserves.(ii)
    
    Drill and equip development wells, development-type stratigraphic test wells, and
service wells, including the costs of platforms and of well equipment such as casing,
tubing, pumping equipment, and the wellhead assembly.




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(iii)
    
    Acquire, construct, and install production facilities such as lease flow lines,
separators, treaters, heaters, manifolds, measuring devices, and production storage
tanks, natural gas cycling and processing plants, and central utility and waste
disposal systems.(iv)
    
    Provide improved recovery systems.
 Development project
 Development well
 Economically producible
 Estimated ultimate recovery (EUR)
 Exploration costs
 (i)
    
    Costs of topographical, geographical and geophysical studies, rights of access to
properties to conduct those studies, and salaries and other expenses of geologists,
geophysical crews, and others conducting those studies.   Collectively, these are
sometimes referred to as geological and geophysical or G&G costs.(ii)
    
    Costs of carrying and retaining undeveloped properties, such as delay rentals, ad
valorem taxes on properties, legal costs for title defense, and the maintenance of land
and lease records.(iii)
    
    Dry hole contributions and bottom hole contributions.(iv)
    
    Costs of drilling and equipping exploratory wells.(v)
    
    Costs of drilling exploratory-type stratigraphic test wells.
 Exploratory well
 Extension well
 Field
 Oil and gas producing activities
 (i)
    
    Oil and gas producing activities include:
 (A)
    
    The search for crude oil, including condensate and natural gas liquids,
or natural gas (oil and gas) in their natural states and original locations;(B)
    
    The acquisition of property rights or properties for the purpose of
further exploration or for the purpose of removing the oil or gas from such
properties;(C)
    
    The construction, drilling, and production activities necessary to
retrieve oil and gas from their natural reservoirs, including the acquisition,
construction, installation, and maintenance of field gathering and storage
systems, such as:
 (1)
    
    Lifting the oil and gas to the surface; and(2)
    
    Gathering, treating, and field processing (as in the case of
processing gas to extract liquid hydrocarbons); and
 (D)
    
    Extraction of saleable hydrocarbons, in the solid, liquid, or gaseous
state, from oil sands, shale, coalbeds, or other nonrenewable natural resources
which are intended to be upgraded into synthetic oil or gas, and activities
undertaken with a view to such extraction.




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Instruction 1 to paragraph (a)(16)(i)
 a.
    
    The first point at which oil, gas, or gas liquids, natural or synthetic, are
delivered to a main pipeline, a common carrier, a refinery, or a marine terminal; andb.
    
    In the case of natural resources that are intended to be upgraded into synthetic
oil or gas, if those natural resources are delivered to a purchaser prior to upgrading,
the first point at which the natural resources are delivered to a main pipeline, a
common carrier, a refinery, a marine terminal, or a facility which upgrades such
natural resources into synthetic oil or gas.
 Instruction 2 to paragraph (a)(16)(i): saleable
hydrocarbons
 (ii)
    
    Oil and gas producing activities do not include:
 (A)
    
    Transporting, refining, or marketing oil and gas;(B)
    
    Processing of produced oil, gas, or natural resources that can be
upgraded into synthetic oil or gas by a registrant that does not have the legal
right to produce or a revenue interest in such production;(C)
    
    Activities relating to the production of natural resources other than
oil, gas, or natural resources from which synthetic oil and gas can be
extracted; or(D)
    
    Production of geothermal steam.
 Possible reserves.
 (i)
    
    When deterministic methods are used, the total quantities ultimately recovered from
a project have a low probability of exceeding proved plus probable plus possible
reserves.   When probabilistic methods are used, there should be at least a 10%
probability that the total quantities ultimately recovered will equal or exceed the
proved plus probable plus possible reserves estimates.(ii)
    
    Possible reserves may be assigned to areas of a reservoir adjacent to probable
reserves where data control and interpretations of available data are progressively
less certain.   Frequently, this will be in areas where geoscience and engineering data
are unable to define clearly the area and vertical limits of commercial production from
the reservoir by a defined project.(iii)
    
    Possible reserves also include incremental quantities associated with a greater
percentage recovery of the hydrocarbons in place than the recovery quantities assumed
for probable reserves.(iv)
    
    The proved plus probable and proved plus probable plus possible reserves estimates
must be based on reasonable alternative technical and commercial interpretations within
the reservoir or subject project that are clearly documented, including comparisons to
results in successful similar projects.(v)
    
    Possible reserves may be assigned where geoscience and engineering data identify
directly adjacent portions of a reservoir within the same accumulation that may be
separated from proved areas by faults with displacement less than formation thickness
or other geological discontinuities and that have not been penetrated by a wellbore,
and the registrant believes that such adjacent portions are in communication with the
known (proved) reservoir.   Possible reserves may be assigned to areas that are
structurally higher or lower than the proved area if these areas are in communication
with the proved reservoir.(vi)
    
    Pursuant to paragraph (a)(22)(iii) of this section, where direct observation has
defined a highest known oil (HKO) elevation and the potential exists for an associated
gas cap, proved oil reserves should be assigned in the structurally higher portions of
the reservoir above the HKO only if the higher contact can be established with
reasonable certainty through reliable technology.   Portions of the reservoir that do
not meet this reasonable certainty criterion may be assigned as probable and possible
oil or gas based on reservoir fluid properties and pressure gradient interpretations.
 Probable reserves.
 (i)
    
    When deterministic methods are used, it is as likely as not that actual remaining
quantities recovered will exceed the sum of estimated proved plus probable reserves.
When probabilistic methods are used, there should be at least a 50% probability that
the actual quantities recovered will equal or exceed the proved plus probable reserves
estimates.(ii)
    
    Probable reserves may be assigned to areas of a reservoir adjacent to proved
reserves where data control or interpretations of available data are less certain, even
if the interpreted reservoir continuity of structure or productivity does not meet the
reasonable certainty criterion.   Probable reserves may be assigned to areas that are
structurally higher than the proved area if these areas are in communication with the
proved reservoir.(iii)
    
    Probable reserves estimates also include potential incremental quantities
associated with a greater percentage recovery of the hydrocarbons in place than assumed
for proved reserves.(iv)
    
    See also guidelines in paragraphs (a)(17)(iv) and (a)(17)(vi) of this section.




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##### 



Probabilistic estimate.
 Production costs
 (i)
    
    Costs incurred to operate and maintain wells and related equipment and facilities,
including depreciation and applicable operating costs of support equipment and
facilities and other costs of operating and maintaining those wells and related
equipment and facilities.   They become part of the cost of oil and gas produced.
Examples of production costs (sometimes called lifting costs) are:
 (A)
    
    Costs of labor to operate the wells and related equipment and
facilities.(B)
    
    Repairs and maintenance.(C)
    
    Materials, supplies, and fuel consumed and supplies utilized in
operating the wells and related equipment and facilities.(D)
    
    Property taxes and insurance applicable to proved properties and wells
and related equipment and facilities.(E)
    
    Severance taxes.
 (ii)
    
    Some support equipment or facilities may serve two or more oil and gas producing
activities and may also serve transportation, refining, and marketing activities.   To
the extent that the support equipment and facilities are used in oil and gas producing
activities, their depreciation and applicable operating costs become exploration,
development or production costs, as appropriate.   Depreciation, depletion, and
amortization of capitalized acquisition, exploration, and development costs are not
production costs but also become part of the cost of oil and gas produced along with
production (lifting) costs identified above.
 Proved area.
 Proved oil and gas reserves.
 (i)
    
    The area of the reservoir considered as proved includes:
 (A)
    
    The area identified by drilling and limited by fluid contacts, if any,
and(B)
    
    Adjacent undrilled portions of the reservoir that can, with reasonable
certainty, be judged to be continuous with it and to contain economically
producible oil or gas on the basis of available geoscience and engineering
data.
 (ii)
    
    In the absence of data on fluid contacts, proved quantities in a reservoir are
limited by the lowest known hydrocarbons (LKH) as seen in a well penetration unless
geoscience, engineering, or performance data and reliable technology establishes a
lower contact with reasonable certainty.(iii)
    
    Where direct observation from well penetrations has defined a highest known oil
(HKO) elevation and the potential exists for an associated gas cap, proved oil reserves
may be assigned in the structurally higher portions of the reservoir only if
geoscience, engineering, or performance data and reliable technology establish the
higher contact with reasonable certainty.(iv)
    
    Reserves which can be produced economically through application of improved
recovery techniques (including, but not limited to, fluid injection) are included in
the proved classification when:
 (A)
    
    Successful testing by a pilot project in an area of the reservoir with
properties no more favorable than in the reservoir as a whole, the operation of
an installed program in the reservoir or an analogous reservoir, or other
evidence using reliable technology establishes the reasonable certainty of the
engineering analysis on which the project or program was based; and(B)
    
    The project has been approved for development by all necessary parties
and entities, including governmental entities.
 (v)
    
    Existing economic conditions include prices and costs at which economic
producibility from a reservoir is to be determined.   The price shall be the average
price during the 12-month period prior to the ending date of the period covered by the
report, determined as an unweighted arithmetic average of the first-day-of-the-month
price for each month within such period, unless prices are defined by contractual
arrangements, excluding escalations based upon future conditions.
 Proved properties.




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##### 



Reasonable certainty.
 Reliable technology.
 Reserves.
 Note to paragraph (a)(26)
 Excerpted from the FASB Accounting Standards Codification Topic 932, Extractive
ActivitiesOil and Gas:
 932-235-50-30 A standardized measure of discounted future net cash flows relating to an
entitys interests in both of the following shall be disclosed as of the end of the year:
 a.
    
    Proved oil and gas reserves (see paragraphs 932-235-50-3 through 50-11B)b.
    
    Oil and gas subject to purchase under long-term supply, purchase, or similar
agreements and contracts in which the entity participates in the operation of the
properties on which the oil or gas is located or otherwise serves as the producer of
those reserves (see paragraph 932-235-50-7).
 The standardized measure of discounted future net cash flows relating to those two types of
interests in reserves may be combined for reporting purposes.
 932-235-50-31 All of the following information shall be disclosed in the aggregate and for
each geographic area for which reserve quantities are disclosed in accordance with
paragraphs 932-235-50-3 through 50-11B:
 a.
    
    Future cash inflows.   These shall be computed by applying prices used in
estimating the entitys proved oil and gas reserves to the year-end quantities of
those reserves.   Future price changes shall be considered only to the extent provided
by contractual arrangements in existence at year-end.b.
    
    Future development and production costs.   These costs shall be computed by
estimating the expenditures to be incurred in developing and producing the proved oil
and gas reserves at the end of the year, based on year-end costs and assuming
continuation of existing economic conditions.   If estimated development expenditures
are significant, they shall be presented separately from estimated production costs.c.
    
    Future income tax expenses.   These expenses shall be computed by applying the
appropriate year-end statutory tax rates, with consideration of future tax rates
already legislated, to the future pretax net cash flows relating to the entitys
proved oil and gas reserves, less the tax basis of the properties involved.   The
future income tax expenses shall give effect to tax deductions and tax credits and
allowances relating to the entitys proved oil and gas reserves.d.
    
    Future net cash flows.   These amounts are the result of subtracting future
development and production costs and future income tax expenses from future cash
inflows.e.
    
    Discount.   This amount shall be derived from using a discount rate of 10
percent a year to reflect the timing of the future net cash flows relating to proved
oil and gas reserves.f.
    
    Standardized measure of discounted future net cash flows.   This amount is the
future net cash flows less the computed discount.
 Reservoir.
 Resources.




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##### 



Service well.
 Stratigraphic test well.
 Undeveloped oil and gas reserves.
 (i)
    
    Reserves on undrilled acreage shall be limited to those directly offsetting
development spacing areas that are reasonably certain of production when drilled,
unless evidence using reliable technology exists that establishes reasonable certainty
of economic producibility at greater distances.(ii)
    
    Undrilled locations can be classified as having undeveloped reserves only if a
development plan has been adopted indicating that they are scheduled to be drilled
within five years, unless the specific circumstances, justify a longer time.
 From the SECs Compliance and Disclosure Interpretations (October 26, 2009):
 Although several types of projects  such as constructing offshore platforms and
development in urban areas, remote locations or environmentally sensitive locations  by
their nature customarily take a longer time to develop and therefore often do justify longer
time periods, this determination must always take into consideration all of the facts and
circumstances.   No particular type of project per se justifies a longer time period, and any
extension beyond five years should be the exception, and not the rule.
 Factors that a company should consider in determining whether or not circumstances justify
recognizing reserves even though development may extend past five years include, but are not
limited to, the following:
 
    
    The companys level of ongoing significant development activities in the area to
be developed (for example, drilling only the minimum number of wells necessary to
maintain the lease generally would not constitute significant development
activities);
    
    The companys historical record at completing development of comparable long-term
projects;
    
    The amount of time in which the company has maintained the leases, or booked the
reserves, without significant development activities;
    
    The extent to which the company has followed a previously adopted development plan
(for example, if a company has changed its development plan several times without
taking significant steps to implement any of those plans, recognizing proved
undeveloped reserves typically would not be appropriate); and
    
    The extent to which delays in development are caused by external factors related
to the physical operating environment (for example, restrictions on development on
Federal lands, but not obtaining government permits), rather than by internal factors
(for example, shifting resources to develop properties with higher priority).
 (iii)
    
    Under no circumstances shall estimates for undeveloped reserves be attributable to
any acreage for which an application of fluid injection or other improved recovery
technique is contemplated, unless such techniques have been proved effective by actual
projects in the same reservoir or an analogous reservoir, as defined in paragraph
(a)(2) of this section, or by other evidence using reliable technology establishing
reasonable certainty.
 Unproved properties.