Attached files
file | filename |
---|---|
10-K - FORM 10-K - DENBURY INC | d71173e10vk.htm |
EX-21 - EX-21 - DENBURY INC | d71173exv21.htm |
EX-32 - EX-32 - DENBURY INC | d71173exv32.htm |
EX-4.H - EX-4.H - DENBURY INC | d71173exv4wh.htm |
EX-4.F - EX-4.F - DENBURY INC | d71173exv4wf.htm |
EX-4.C - EX-4.C - DENBURY INC | d71173exv4wc.htm |
EX-10.H - EX-10.H - DENBURY INC | d71173exv10wh.htm |
EX-23.B - EX-23.B - DENBURY INC | d71173exv23wb.htm |
EX-23.A - EX-23.A - DENBURY INC | d71173exv23wa.htm |
EX-31.A - EX-31.A - DENBURY INC | d71173exv31wa.htm |
EX-10.G - EX-10.G - DENBURY INC | d71173exv10wg.htm |
EX-31.B - EX-31.B - DENBURY INC | d71173exv31wb.htm |
EXCEL - IDEA: XBRL DOCUMENT - DENBURY INC | Financial_Report.xls |
Exhibit 99
DeGolyer and MacNaughton
5001 Spring Valley Road
Suite 800 East
Dallas, Texas 75244
5001 Spring Valley Road
Suite 800 East
Dallas, Texas 75244
APPRAISAL REPORT
as of
DECEMBER 31, 2009
on
PROVED RESERVES
of
CERTAIN PROPERTIES
owned by
DENBURY RESOURCES INC.
as of
DECEMBER 31, 2009
on
PROVED RESERVES
of
CERTAIN PROPERTIES
owned by
DENBURY RESOURCES INC.
SEC CASE
DeGolyer and MacNaughton
5001 Spring Valley Road
Suite 800 East
Dallas, Texas 75244
5001 Spring Valley Road
Suite 800 East
Dallas, Texas 75244
APPRAISAL REPORT
as of
DECEMBER 31, 2009
on
PROVED RESERVES
of
CERTAIN PROPERTIES
owned by
DENBURY RESOURCES INC.
as of
DECEMBER 31, 2009
on
PROVED RESERVES
of
CERTAIN PROPERTIES
owned by
DENBURY RESOURCES INC.
SEC CASE
FOREWORD
Scope of Investigation
This report presents an appraisal, as of
December 31, 2009, of the extent and value of the proved crude oil, condensate, natural gas
liquids, and natural gas reserves of certain properties owned by Denbury Resources Inc. (Denbury).
Estimates of carbon dioxide gas reserves are also included. The reserves estimated in this report
are located in Alabama, Arkansas, Louisiana, Mississippi, and Texas and represent 100 percent of
Denburys proved reserves. The properties appraised are listed in detail in the related DeGolyer
and MacNaughton report entitled Appraisal Report as of December 31, 2009 on Certain Properties
owned by Denbury Resources Inc. SEC Case.
Reserves estimated in this report are expressed as gross and net reserves. Gross reserves are
defined as the total estimated petroleum to be produced from these properties after December 31,
2009. Net reserves are defined as that portion of the gross reserves attributable to the interests
owned by Denbury after deducting royalties and interests owned by others.
This report also presents values that were estimated for proved reserves using initial prices and
costs provided by Denbury. Prices are related to December 31, 2009, NYMEX prices of $61.18 per
barrel and
2
DeGolyer and MacNaughton
$4.189 per million British thermal units (MMBtu). No escalation has been applied to prices and
costs. A detailed explanation of the future price and cost assumptions is included in the Valuation
of Reserves section of this report.
Values of proved reserves in this report are expressed in terms of estimated future gross
revenue, future net revenue, and present worth. Future gross revenue is that revenue which will
accrue to the appraised interests from the production and sale of the estimated net reserves.
Future net revenue is calculated by deducting estimated production taxes, ad valorem taxes,
operating expenses, and capital costs from the future gross revenue. Operating expenses include
field operating expenses, transportation expenses, compression charges, and an allocation of
overhead that directly relates to production activities. Future income tax expenses were not taken
into account in the preparation of these estimates. Present worth is defined as future net revenue
discounted at a specified arbitrary discount rate compounded monthly over the expected period of
realization. In this report, present worth values using a discount rate of 10 percent are reported.
Estimates of oil, condensate, natural gas liquids, gas reserves, and future net revenue should
be regarded only as estimates that may change as further production history and additional
information become available. Not only are such reserves and revenue estimates based on that
information which is currently available, but such estimates are also subject to the uncertainties
inherent in the application of judgmental factors in interpreting such information.
Authority
This report was prepared at the request of
Mr. David Heather, Chairman of the Reserves Committee of the Board of Directors, Denbury.
Source of Information
Data used in the preparation of this
report were obtained from Denbury, from records on file with the appropriate regulatory
agencies, and from public sources. In the preparation of this report we have relied, without
independent verification, upon information furnished by Denbury with respect to its property
interests, production from such properties, current costs of operation and development, current
prices for production, agreements relating to current and future operations and sale of
3
DeGolyer and MacNaughton
production,
and various other information and data that were accepted as represented. A field examination of
the properties was not considered necessary for the purposes of this report.
4
DeGolyer and MacNaughton
DEFINITION of RESERVES
Petroleum reserves included in this report are classified as proved. Only proved reserves have
been evaluated for this report. Reserves classifications used in this report are in accordance with
the reserves definitions of Rules 410(a) (1)(32) of Regulation SX of the SEC. Reserves are
judged to be economically producible in future years from known reservoirs under existing economic
and operating conditions and assuming continuation of current regulatory practices using
conventional production methods and equipment. In the analyses of production-decline curves,
reserves were estimated only to the limit of economic rates of production under existing economic
and operating conditions using prices and costs consistent with the effective date of this report,
including consideration of changes in existing prices provided only by contractual arrangements but
not including escalations based upon future conditions. The petroleum reserves are classified as
follows:
Proved oil and gas reserves Proved oil and gas reserves are those quantities of
oil and gas, which, by analysis of geoscience and engineering data, can be
estimated with reasonable certainty to be economically produciblefrom a given
date forward, from known reservoirs, and under existing economic conditions,
operating methods, and government regulationsprior to the time at which
contracts providing the right to operate expire, unless evidence indicates that
renewal is reasonably certain, regardless of whether deterministic or
probabilistic methods are used for the estimation. The project to extract the
hydrocarbons must have commenced or the operator must be reasonably certain that
it will commence the project within a reasonable time.
(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,
5
DeGolyer and MacNaughton
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.
Probable reserves Probable reserves are those additional reserves that are less
certain to be recovered than proved reserves but which, together with proved
reserves, are as likely as not to be recovered.
6
DeGolyer and MacNaughton
(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 (iv) and (vi) of the definition of
possible reserves.
Possible reserves Possible reserves are those additional reserves that are less
certain to be recovered than probable 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
7
DeGolyer and MacNaughton
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 (iii) of the proved oil and gas definition,
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.
8
DeGolyer and MacNaughton
Developed oil and gas reserves Developed oil and gas reserves are reserves of
any category that can be expected to be recovered:
(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.
Undeveloped reserves Undeveloped oil and gas reserves are reserves of any
category that are expected to be recovered from new wells on undrilled acreage, or
from existing wells where a relatively major expenditure is required for
recompletion.
(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.
(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 [section 210.410 (a) Definitions], or
by other evidence using reliable technology establishing reasonable
certainty.
The extent to which probable and possible reserves ultimately may be reclassified as proved
reserves is dependent upon future
9
DeGolyer and MacNaughton
drilling, testing, and well performance. The degree of risk to be
applied in evaluating probable and possible reserves is influenced by economic and technological
factors as well as the time element. No probable or possible reserves have been evaluated for this
report.
10
DeGolyer and MacNaughton
ESTIMATION of RESERVES
Estimates of reserves were prepared by the use of geological and engineering methods generally
accepted by the petroleum industry. The method or combination of methods used in the analysis of
each reservoir was tempered by experience with similar reservoirs, stage of development, quality
and completeness of basic data, and production history.
When applicable, the volumetric method was used to estimate the original oil in place (OOIP)
and original gas in place (OGIP). Structure maps were prepared to delineate each reservoir, and
isopach maps were constructed to estimate reservoir volume. Electrical logs, radioactivity logs,
core analyses, and other available data were used to prepare these maps as well as to estimate
representative values for porosity and water saturation. When adequate data were available and when
circumstances justified, material-balance and other engineering methods were used to estimate OOIP
or OGIP.
Estimates of ultimate recovery were obtained after applying recovery factors to OOIP or OGIP.
These recovery factors were based on consideration of the type of energy inherent in the
reservoirs, analyses of the petroleum, the structural positions of the properties, and the
production histories. When applicable, material-balance and other engineering methods were used to
estimate recovery factors. An analysis of reservoir performance, including production rate,
reservoir pressure, and gas-oil ratio behavior, was used in the estimation of reserves.
For depletion-type reservoirs or those whose performance disclosed a reliable decline in
producing-rate trends or other diagnostic characteristics, reserves were estimated by the
application of appropriate decline curves or other performance relationships. In the analyses of
production-decline curves, reserves were estimated only to the limits of economic production based
on current economic conditions.
In certain cases, when the previously named methods could not be used, reserves were estimated
by analogy with similar wells or reservoirs for which more complete data were available.
The gas reserves included herein are reported as sales gas. Sales gas is defined as that gas
to be delivered into a gas
11
DeGolyer and MacNaughton
pipeline for sale after separation, processing, fuel use, and flare. All
gas quantities are expressed at a temperature base of 60 degrees Fahrenheit (°F) and at the legal
pressure base of the state or area in which the reserves are located. Condensate reserves estimated
herein are those to be recovered by
conventional lease separation. Natural gas liquids reserves are estimated to be those
attributable to the leasehold interests appraised based on historical yield information.
In the preparation of this study, as of December 31, 2009, gross production estimated to
December 31, 2009, was deducted from gross ultimate recovery to arrive at the estimate of gross
reserves. In some fields, this required that the production rates be estimated for up to 2 months,
since production data from certain properties were available only through October 2009.
The following table presents estimates of the proved reserves, as of December 31, 2009, of the
properties appraised, expressed in thousands of barrels (Mbbl) or millions of cubic feet (MMcf):
Oil and | Natural Gas | Total | ||||||||||||||
Condensate | Liquids | Liquids | Gas | |||||||||||||
(Mbbl) | (Mbbl) | (Mbbl) | (MMcf) | |||||||||||||
Gross Proved Reserves |
||||||||||||||||
Developed Producing |
141,092 | 2,054 | 143,146 | 157,018 | ||||||||||||
Developed Nonproducing |
28,716 | 141 | 28,856 | 7,400 | ||||||||||||
Undeveloped |
96,991 | 0 | 96,991 | 24,775 | ||||||||||||
Total Gross Reserves |
266,799 | 2,195 | 268,993 | 189,193 | ||||||||||||
Net Proved Reserves |
||||||||||||||||
Developed Producing |
92,480 | 1,353 | 93,833 | 67,952 | ||||||||||||
Developed Nonproducing |
22,263 | 96 | 22,359 | 1,561 | ||||||||||||
Undeveloped |
76,687 | 0 | 76,687 | 18,462 | ||||||||||||
Total Net Reserves |
191,430 | 1,449 | 192,879 | 87,975 |
In addition to the natural gas reserves shown in the foregoing tabulation, Denburys net
proved carbon dioxide gas reserves in Mississippi, as of December 31, 2009, are estimated to be
5,010,437 MMcf. This amount includes 4,555,449 MMcf of developed reserves and 454,988 MMcf of
undeveloped reserves. The gross proved carbon dioxide gas reserves for the appraised properties are
6,302,836 MMcf, of which 5,720,236 MMcf are developed. The carbon dioxide gas reserves have been
prepared under the same guidelines as
12
DeGolyer and MacNaughton
those for oil and natural gas. No revenue estimates have been
made for the carbon dioxide reserves.
13
DeGolyer and MacNaughton
VALUATION of RESERVES
Revenue values in this report were estimated using the initial prices and costs provided by
Denbury. Future prices were estimated using guidelines established by the SEC and the Financial
Accounting Standards Board (FASB).
In this report, values for proved reserves were based on projections of estimated future
production and revenue prepared for these properties.
The following assumptions were used for estimating future prices and costs:
Oil and Condensate Prices
Oil and condensate prices were calculated using differentials furnished by
Denbury for each lease to a NYMEX price of $61.18 per barrel and held
constant thereafter. The weighted average price over the lives of the
properties was $58.36 per barrel.
Natural Gas Liquids Prices
Natural gas liquids prices were calculated using the 2008 average ratio to
the NYMEX oil price of $61.18 per barrel. These prices were held constant
over the lives of the properties. The average price over the lives of the
properties is $38.56 per barrel.
Natural Gas Prices
Natural gas prices were calculated for each lease using differentials
furnished by Denbury to a NYMEX price of $4.189 per MMBtu and held
constant thereafter. The weighted average price over the lives of the
properties was $3.989 per thousand cubic feet.
14
DeGolyer and MacNaughton
Operating Expenses and Capital Costs
Current operating expenses and capital costs, based on information
provided by Denbury, were used in estimating future costs required to
operate the properties. In certain cases, future costs, either higher or
lower than current costs, may have been used because of anticipated
changes in operating conditions. These costs were not escalated for
inflation.
The future revenue to be derived from the production and sale of the proved reserves, as of
December 31, 2009, of the properties appraised is estimated as follows:
Proved | ||||||||||||||||
Developed | Developed | Total | ||||||||||||||
Producing | Nonproducing | Undeveloped | Proved | |||||||||||||
(M$) | (M$) | (M$) | (M$) | |||||||||||||
Future Gross Revenue |
5,763,737 | 1,292,728 | 4,522,693 | 11,579,158 | ||||||||||||
Production and Ad Valorem Taxes |
269,525 | 61,066 | 157,206 | 487,797 | ||||||||||||
Operating Expenses |
2,715,423 | 542,484 | 1,288,689 | 4,546,596 | ||||||||||||
Capital Costs |
62,827 | 57,813 | 646,553 | 767,193 | ||||||||||||
Abandonment Costs |
69,527 | (265 | ) | 0 | 69,262 | |||||||||||
Future Net Revenue* |
2,646,435 | 631,630 | 2,430,245 | 5,708,310 | ||||||||||||
Present Worth at 10 Percent* |
1,677,167 | 382,129 | 1,016,163 | 3,075,459 |
* | Future income taxes have not been taken into account in the preparation of these estimates. | |
Note: Numbers in tables may not add due to rounding. |
Timing of capital expenditures and the resulting development of production were based on
a development plan provided by Denbury.
In our opinion, the information relating to estimated proved reserves of oil, condensate, NGL,
and natural gas, estimated future net revenue from those proved reserves, and present worth of
estimated future net revenue from proved reserves of oil, condensate, natural gas liquids, and gas
contained in this report has been prepared in accordance with Paragraphs 932-235-50-4,
932-235-50-6, 932-235-50-7, 932-235-50-9, 932-235-50-30, and 932-235-50-31(a), (b), and (e) of the
Accounting Standards Update 932-235-50, Extractive Industries Oil and Gas (Topic 932): Oil and
Gas Reserve Estimation and Disclosures (January 2010) of the Financial Accounting Standards Board
and Rules 410(a) (1)(32) of Regulation SX and Rules 302(b), 1201, 1202(a) (1), (2), (3), (4),
(8), and 1203(a) of Regulation SK of the Securities and Exchange Commission;
15
DeGolyer and MacNaughton
provided, however,
future income tax expenses have not been taken into account in estimating the future net revenue
and present worth values set forth herein.
To the extent that the above-enumerated rules, regulations, and statements require
determinations of an accounting or legal nature or information beyond the scope of our report, we
are necessarily unable to express an opinion as to whether the above-described information is in
accordance therewith or sufficient therefore.
16
DeGolyer and MacNaughton
SUMMARY and CONCLUSIONS
Denbury owns working and royalty interests in certain properties located in Alabama, Arkansas,
Louisiana, Mississippi, and Texas. The estimated net proved reserves of the properties appraised,
as of December 31, 2009, are summarized as follows, expressed in thousands of barrels (Mbbl) or
millions of cubic feet (MMcf):
Oil and | Natural Gas | Total | ||||||||||||||
Condensate | Liquids | Liquids | Gas | |||||||||||||
(Mbbl) | (Mbbl) | (Mbbl) | (MMcf) | |||||||||||||
Net Proved Reserves |
||||||||||||||||
Developed Producing |
92,480 | 1,353 | 93,833 | 67,952 | ||||||||||||
Developed Nonproducing |
22,263 | 96 | 22,359 | 1,561 | ||||||||||||
Undeveloped |
76,687 | 0 | 76,687 | 18,462 | ||||||||||||
Total Net Reserves |
191,430 | 1,449 | 192,879 | 87,975 |
The estimated revenue and expenditures attributable to Denburys interests in the proved
reserves, as of December 31, 2009, of the properties appraised under the aforementioned assumptions
concerning future prices and costs are summarized as follows:
Proved | ||||||||||||||||
Developed | Developed | Total | ||||||||||||||
Producing | Nonproducing | Undeveloped | Proved | |||||||||||||
(M$) | (M$) | (M$) | (M$) | |||||||||||||
Future Gross Revenue |
5,763,737 | 1,292,728 | 4,522,693 | 11,579,158 | ||||||||||||
Production and Ad Valorem Taxes |
269,525 | 61,066 | 157,206 | 487,797 | ||||||||||||
Operating Expenses |
2,715,423 | 542,484 | 1,288,689 | 4,546,596 | ||||||||||||
Capital Costs |
62,827 | 57,813 | 646,553 | 767,193 | ||||||||||||
Abandonment Costs |
69,527 | (265 | ) | 0 | 69,262 | |||||||||||
Future Net Revenue* |
2,646,435 | 631,630 | 2,430,245 | 5,708,310 | ||||||||||||
Present Worth at 10 Percent* |
1,677,167 | 382,129 | 1,016,163 | 3,075,459 |
* | Future income taxes have not been taken into account in the preparation of these estimates. | |
Note: Numbers in tables may not add due to rounding. |
While the oil and gas industry may be subject to regulatory changes from time to time
that could affect an industry participants ability to recover its oil and gas reserves, we are not
aware of any such governmental actions which would restrict the recovery of the December 31, 2009,
estimated oil and gas volumes. The reserves estimated in this report can be produced under current
regulatory guidelines.
17
DeGolyer and MacNaughton
DeGolyer and MacNaughton is an independent petroleum engineering consulting firm that has been
providing petroleum consulting services throughout the world for over 70 years. DeGolyer and
MacNaughton does not have any financial interest, including stock ownership, in Denbury. Our fees
were not contingent on the results of our evaluation. This report has been prepared at the request
of Denbury and should not be used for purposes other than those for which it is intended. DeGolyer
and MacNaughton has used all procedures, data, and methods that it considers necessary to prepare
this report.
All gas quantities in this report are expressed at a temperature base of 60 °F and at the
legal pressure base of the state or area in which the reserves are located.
Submitted, |
||||
/s/ DeGolyer and MacNaughton | ||||
DeGOLYER and MacNAUGHTON | ||||
Texas Registered Engineering Firm F-716 | ||||
SIGNED: January 26, 2010
/s/ Paul J. Szatkowski PE | ||||
Paul J. Szatkowski, P.E. | ||||
Senior Vice President DeGolyer and MacNaughton |
||||
DeGolyer and MacNaughton
TABLE of CONTENTS
Page | ||||
FOREWORD |
1 | |||
Scope of Investigation |
1 | |||
Authority |
2 | |||
Source of Information |
2 | |||
DEFINITION of RESERVES |
4 | |||
ESTIMATION of RESERVES |
10 | |||
VALUATION of RESERVES |
13 | |||
SUMMARY and CONCLUSIONS |
16 | |||
CERTIFICATE of QUALIFICATION |
DeGolyer and MacNaughton
CERTIFICATE of QUALIFICATION
I, Paul J. Szatkowski, Petroleum Engineer with DeGolyer and MacNaughton, 5001 Spring Valley Road,
Suite 800 East, Dallas, Texas 75244, U.S.A., hereby certify:
1. | That I am a Senior Vice President with DeGolyer and MacNaughton, which company did prepare the report entitled Appraisal Report as of December 31, 2009 on Proved Reserves of Certain Properties owned by Denbury Resources Inc. SEC Case dated January 26, 2010, and that I, as Senior Vice President, was responsible for the preparation of this report. | ||
2. | That I attended Texas A&M University, and that I graduated with a Bachelor of Science degree in Petroleum Engineering in the year 1974; that I am a Registered Professional Engineer in the State of Texas; that I am a member of the International Society of Petroleum Engineers; and that I have in excess of thirty-five (35) years of experience in oil and gas reservoir studies and evaluations. | ||
3. | That DeGolyer and MacNaughton or its officers have no direct or indirect interest, nor do they expect to receive any direct or indirect interest in any properties or securities of Denbury or affiliate thereof. |
SIGNED: January 26, 2010
/s/ Paul J. Szatkowski, PE / | ||||
Paul J. Szatkowski, P.E. | ||||
Senior Vice President DeGolyer and MacNaughton |
||||