Attached files
file | filename |
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10-K - FORM 10-K - MAGNUM HUNTER RESOURCES CORP | h79663e10vk.htm |
EX-4.1 - EX-4.1 - MAGNUM HUNTER RESOURCES CORP | h79663exv4w1.htm |
EX-10.8 - EX-10.8 - MAGNUM HUNTER RESOURCES CORP | h79663exv10w8.htm |
EX-23.1 - EX-23.1 - MAGNUM HUNTER RESOURCES CORP | h79663exv23w1.htm |
EX-10.9 - EX-10.9 - MAGNUM HUNTER RESOURCES CORP | h79663exv10w9.htm |
EX-21.1 - EX-21.1 - MAGNUM HUNTER RESOURCES CORP | h79663exv21w1.htm |
EX-23.3 - EX-23.3 - MAGNUM HUNTER RESOURCES CORP | h79663exv23w3.htm |
EX-31.2 - EX-31.2 - MAGNUM HUNTER RESOURCES CORP | h79663exv31w2.htm |
EX-31.1 - EX-31.1 - MAGNUM HUNTER RESOURCES CORP | h79663exv31w1.htm |
EX-32.1 - EX-32.1 - MAGNUM HUNTER RESOURCES CORP | h79663exv32w1.htm |
EX-23.2 - EX-23.2 - MAGNUM HUNTER RESOURCES CORP | h79663exv23w2.htm |
EX-10.18 - EX-10.18 - MAGNUM HUNTER RESOURCES CORP | h79663exv10w18.htm |
EX-10.11 - EX-10.11 - MAGNUM HUNTER RESOURCES CORP | h79663exv10w11.htm |
Exhibit 99.1
PETROLEUM CONSULTANTS
9601 AMBERGLEN BLVD., SUITE 117
|
306 WEST SEVENTH STREET, SUITE 302 | 1000 LOUISIANA STREET, SUITE 625 | ||
AUSTIN, TEXAS 78729-1106
|
FORT WORTH, TEXAS 76102-4987 | HOUSTON, TEXAS 77002-5008 | ||
512-249-7000
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817-336-2461 | 713-651-9944 | ||
FAX 512-233-2618
|
FAX 817-877-3728 www.cgaus.com |
FAX 713-651-9980 |
January 19, 2011
Magnum Hunter Resources Corporation
777 Post Oak Blvd, Suite 910 Houston,
Texas 77056
777 Post Oak Blvd, Suite 910 Houston,
Texas 77056
Re: | Evaluation Summary Magnum Hunter Resources Corp. Interests Total Proved Reserves As of December 31, 2010 Pursuant to the Guidelines of the Securities and Exchange Commission for Reporting Corporate Reserves and Future Net Revenue |
Ladies and Gentlemen:
As requested, this report was prepared on January 19, 2010 for Magnum Hunter Resources
Corporation (MHR) for the purpose of submitting our estimates of proved reserves and forecasts
of economics attributable to the subject interests. We evaluated 100% of MHR reserves, which are
made up of oil and gas properties in various fields throughout the United States. This report,
with an effective date of December 31, 2010, was prepared using constant prices and costs and
conforms to the guidelines of the Securities and Exchange Commission (SEC). The results of this
evaluation are presented in the accompanying tabulations, with a composite summary of the values
presented below:
Proved | Proved | |||||||||||||||||||||||
Developed | Developed | Proved | Proved | Total | ||||||||||||||||||||
Producing | Non-Producing | Developed | Undeveloped | Proved | ||||||||||||||||||||
Net Reserves |
||||||||||||||||||||||||
Oil |
- Mbbl | 3,608.8 | 111.5 | 3,720.4 | 3,104.0 | 6,824.4 | ||||||||||||||||||
Gas |
- MMcf | 13,401.3 | 5,486.4 | 18,887.7 | 20,564.2 | 39,451.9 | ||||||||||||||||||
NGL |
- Mbbl | 0.0 | 0.0 | 0.0 | 0.0 | 0.0 | ||||||||||||||||||
Revenue |
||||||||||||||||||||||||
Oil |
- M$ | 259,287.1 | 8,027.4 | 267,314.5 | 222,638.9 | 489,953.5 | ||||||||||||||||||
Gas |
- M$ | 69,035.0 | 28,777.2 | 97,812.2 | 119,299.6 | 217,111.8 | ||||||||||||||||||
NGL |
- M$ | 0.0 | 0.0 | 0.0 | 0.0 | 0.0 | ||||||||||||||||||
Other |
- M$ | 2,722.8 | 0.0 | 2,722.8 | 0.0 | 2,722.8 | ||||||||||||||||||
Severance Taxes |
- M$ | 16,989.0 | 2,106.7 | 19,095.7 | 18,450.9 | 37,546.5 | ||||||||||||||||||
Ad Valorem Taxes |
- M$ | 4,832.2 | 654.6 | 5,486.8 | 4,250.2 | 9,737.0 | ||||||||||||||||||
Operating Expenses |
- M$ | 132,734.2 | 5,637.0 | 138,371.2 | 67,889.0 | 206,260.3 | ||||||||||||||||||
Other Deductions |
- M$ | 0.0 | 0.0 | 0.0 | 0.0 | 0.0 | ||||||||||||||||||
Investments |
- M$ | 22.9 | 5,165.0 | 5,187.9 | 72,028.0 | 77,215.9 | ||||||||||||||||||
Net Cash Flows |
- M$ | 176,466.6 | 23,241.3 | 199,707.9 | 179,320.5 | 379,028.4 | ||||||||||||||||||
Discounted @ 10% (Present Worth) |
- M$ | 101,272.6 | 10,507.5 | 111,780.1 | 66,034.2 | 177,814.3 |
Magnum Hunter Resources Corporation
January 19, 2011
Page 2
January 19, 2011
Page 2
Future revenue is prior to deducting state production taxes and ad valorem taxes. Future net
cash flow is after deducting these taxes, future capital costs and operating expenses, but before
consideration of federal income taxes. In accordance with SEC guidelines, the future net cash flow
has been discounted at an annual rate of ten percent to determine its present worth. The present
worth is shown to indicate the effect of time on the value of money and should not be construed as
being the fair market value of the properties.
The oil reserves include oil and condensate. Oil volumes are expressed in barrels (42 U.S.
gallons). Gas volumes are expressed in thousands of standard cubic feet (Mcf) at contract
temperature and pressure base.
Our estimates are for proved reserves only and do not include any probable or possible
reserves nor have any values been attributed to interest in acreage beyond the location for which
undeveloped reserves have been estimated. The Proved Developed category is the summation of the
Proved Developed Producing and Proved Developed Non-Producing estimates.
Presentation
This report presents two different pricing scenarios, which include the SEC Pricing case and a
Strip Pricing case. The SEC Pricing case is divided into seven main sections: Within each main
section, the reserves are categorized further by the following reserve categories as applicable:
Total Proved (TP), Proved Developed (PD), Proved Developed Producing (PDP), Proved Developed
Non-Producing (PDNP) and Proved Undeveloped (PUD). Within each reserve category section are
Tables I and Summary Plots. Tables II are also included in all cases except for summary sections.
The Tables I present composite reserve estimates and economic forecasts for the particular reserve
category or property grouping. The Summary Plots are composite rate-time history-forecast curves
for the corresponding Table I. Following certain Summary Plots are Table II oneline summaries
that present estimates of ultimate recovery, gross and net reserves, ownership, revenue, expenses,
investments, net income and discounted cash flow for the individual properties that make up the
corresponding Table I.
The Strip Pricing sensitivity case is presented in the Appendix, with the price deck described
in more detail below. For a more detailed explanation of the report layout, please refer to the
Table of Contents following this letter. The data presented in the composite Tables I are explained
in page 1 of the Appendix.
Hydrocarbon Pricing
The base SEC oil and gas prices calculated for December 31, 2010 were $79.43/bbl and
$4.37/MMBTU, respectively. As specified by the SEC, a company must use a 12-month average price,
calculated as the unweighted arithmetic average of the first-day-of-the-month price for each month
within the 12-month period prior to the end of the reporting period. The base oil price is based
upon WTI-Cushing spot prices (EIA) during 2010 and the base gas price is based upon Henry Hub spot
prices (EIA) during 2010. As requested by MHR, an additional price Strip Pricing case was prepared
and is presented in the Appendix. The Strip Pricing case oil and gas prices were applied based on a
NYMEX future strip price deck as quoted on December 31, 2010 and is provided below.
Magnum Hunter Resources Corporation
January 19, 2011
Page 3
January 19, 2011
Page 3
SEC Pricing | Strip Pricing | |||||||||||||||
Avg. Jan.-Dec. 2010 | NYMEX 12-31-2010 Pricing | |||||||||||||||
WTI Cushing | Henry Hub | WTI Cushing | Henry Hub | |||||||||||||
Oil Price | Gas Price | Oil Price | Gas Price | |||||||||||||
Year | $/STB | $/MMBTU | $/STB | $/MMBTU | ||||||||||||
2011 |
79.43 | 4.37 | 93.21 | 4.55 | ||||||||||||
2012 |
| | 93.95 | 5.08 | ||||||||||||
2013 |
| | 92.95 | 5.33 | ||||||||||||
2014 |
| | 92.40 | 5.49 | ||||||||||||
2015+ |
79.43 | 4.37 | 92.55 | 5.64 |
The base prices shown above were adjusted for differentials on a per-property basis, which may
include local basis differentials, transportation, gas shrinkage, gas heating value (BTU content)
and/or crude quality and gravity corrections. After these adjustments, the net realized prices for
the SEC price case over the life of the proved properties was estimated to be $71.795 per barrel
for oil and $5.503 per MCF for gas. All economic factors were held constant in accordance with SEC
guidelines.
Economic Parameters
Ownership was accepted as furnished and has not been independently confirmed. Oil and gas
price differentials, gas shrinkage, ad valorem taxes, severance taxes, lease operating expenses and
investments were calculated and prepared by MHR and were thoroughly reviewed by us for accuracy and
completeness. Lease operating expenses were either determined at the field or individual well level
using averages calculated from historical lease operating statements. All economic parameters,
including lease operating expenses and investments, were held constant (not escalated) throughout
the life of these properties.
SEC Conformance and Regulations
The reserve classifications and the economic considerations used herein conform to the
criteria of the SEC as defined in pages 3 and 4 of the Appendix. The reserves and economics are
predicated on regulatory agency classifications, rules, policies, laws, taxes and royalties
currently in effect except as noted herein. The possible effects of changes in legislation or other
Federal or State restrictive actions which could affect the reserves and economics have not been
considered. However, we do not anticipate nor are we aware of any legislative changes or
restrictive regulatory actions that may impact the recovery of reserves.
This evaluation includes 181 proved undeveloped locations, which includes one (1) location in
the Chalkley asset group (Louisiana), 15 locations in the PRC Williston LLC asset group (North
Dakota), seven (7) locations in the PostRock asset group (West Virginia) and 146 locations in the
Triad Hunter asset group (WV, OH & KY). Each of these drilling locations proposed as part of MHRs
development plans conforms to the proved undeveloped standards as set forth by the SEC. In our
opinion, MHR has indicated they have every intent to complete this development plan within the next
five years. Furthermore, MHR has demonstrated that they have the proper company staffing, financial
backing and prior development success to ensure this five year development plan will be fully
executed.
Reserve Estimation Methods
The methods employed in estimating reserves are described in page 2 of the Appendix. Reserves
for proved developed producing wells were estimated using production performance methods for the
vast majority of properties. Certain new producing properties with very little production history
were forecast using a combination of production performance and analogy to similar production, both
of which are considered to provide a relatively high degree of accuracy.
Magnum Hunter Resources Corporation
January 19, 2011
Page 4
January 19, 2011
Page 4
Non-producing reserve estimates, for both developed and undeveloped properties, were forecast
using either volumetric or analogy methods, or a combination of both. These methods provide a
relatively high degree of accuracy for predicting proved developed non-producing and proved
undeveloped reserves for MHR properties, due to the mature nature of their properties
targeted for development and an abundance of subsurface control data. The assumptions, data,
methods and procedures used herein are appropriate for the purpose served by this report.
General Discussion
The estimates and forecasts were based upon interpretations of data furnished by your office
and available from our files. To some extent information from public records has been used to check
and/or supplement these data. The basic engineering and geological data were subject to third party
reservations and qualifications. Nothing has come to our attention, however, that would cause us to
believe that we are not justified in relying on such data. All estimates represent our best
judgment based on the data available at the time of preparation. Due to inherent uncertainties in
future production rates, commodity prices and geologic conditions, it should be realized that the
reserve estimates, the reserves actually recovered, the revenue derived therefrom and the actual
cost incurred could be more or less than the estimated amounts.
An on-site field inspection of the properties has not been performed. The mechanical operation
or condition of the wells and their related facilities have not been examined nor have the
wells been tested by Cawley, Gillespie & Associates, Inc. Possible environmental liability related
to the properties has not been investigated nor considered. The cost of plugging and the salvage
value of equipment at abandonment have not been included except for the East Texas properties.
Abandonment costs as provided by MHR were applied for the East Texas properties.
Cawley, Gillespie & Associates, Inc. is a Texas Registered Engineering Firm (F-693),
made up of independent registered professional engineers and geologists that have provided
petroleum consulting services to the oil and gas industry for over 50 years. This evaluation was
supervised by W. Todd Brooker, Vice President at Cawley, Gillespie & Associates, Inc. and
a State of Texas Licensed Professional Engineer (License #83462). We do not own an interest in the
properties or Magnum Hunter Resources Corporation and are not employed on a contingent basis. We
have used all methods and procedures that we consider necessary under the circumstances to prepare
this report. Our work-papers and related data utilized in the preparation of these estimates are
available in our office.
Yours very truly, CAWLEY, GILLESPIE & ASSOCIATES, INC. Texas Registered Engineering Firm F-693 |
||||
W. Todd Brooker, P. E. | ||||
Vice President | ||||