Attached files
Exhibit 99.1
February 2, 2010
Mr. Ken Kenworthy
GMX Resources Inc.
One Benham Place, Suite 600
9400 North Broadway
Oklahoma City, OK 73114
Dear Mr. Kenworthy:
Pursuant to your request, MHA Petroleum Consultants, Inc. (MHA) has prepared an estimate of the reserves and income attributable to certain oil and gas properties owned by GMX Resources Inc. (GMX) as of December 31, 2009. It is MHA’s understanding that the proved reserves estimated in this report constitute all of the proved reserves owned by GMX. The subject properties are located in the states of Texas, Louisiana, and New Mexico. This report has been prepared for GMX’s use in filing with the Securities and Exchange Commission (“SEC”).
The reserve and income data have been estimated using the SEC technical guidelines, as modified at year-end 2009. Forecast oil and gas prices and all operating costs remain constant for the life of the wells. Reserve estimates and cash flow estimates are dependent on the pricing and cost parameters used in the report. Future variations in the pricing and cost parameters will cause variations in the reserve and cash flow estimates reported in the evaluation. The results of this study are summarized below.
GMX Resources Inc.
Reserves and Net Income – As of December 31, 2009
| Reserve Category |
Gross Oil MBBLS |
Gross Gas MMCF |
Net Oil MBBLS |
Net Gas MMCF |
BFIT Net Income M$ |
BFIT Net Income Disc @10% M$ | ||||||
| Proved Developed Producing |
2,012.8 | 185,338.2 | 946.8 | 101,120.4 | 228,602.5 | 125,279.4 | ||||||
| Proved Non Producing |
5.8 | 1,034.5 | 3.9 | 698.7 | 1,600.9 | 856.0 | ||||||
| Proved Behind Pipe |
763.1 | 47,903.4 | 488.4 | 22,791.6 | 80,491.0 | 19,777.1 | ||||||
| Proved Undeveloped |
3,532.9 | 308,418.4 | 2,239.9 | 208,600.8 | 315,004.0 | 42,665.8 | ||||||
| Total Proved |
6,314.6 | 542,694.6 | 3,679.0 | 333,211.6 | 625,698.5 | 188,578.3 |
Numbers in the above table may not exactly match economic output due to rounding.
| 143 Union Blvd., Suite 200 | Lakewood, Colorado 80228 USA | Telephone: 303-277-0270 | Fax: 303-277-0276 |
The future net revenue in this report was based on net hydrocarbon volume sold multiplied by the appropriate price. Expenses include severance and ad valorem taxes, and the normal cost of operating the wells. Future net cash flow is future net revenue minus expenses and any development costs. The future net cash flow has not been adjusted for outstanding loans, which may exist, nor does it include any adjustments for cash on hand or undistributed income. No attempt has been made to quantify or otherwise account for any accumulated gas production imbalances that may exist.
Reserve Estimates
Reserve estimates included in this study were assigned on the basis of the Securities and Exchange Commission definitions (as of year-end 2009). These definitions are included in the section of this report titled Reserve Definitions.
The reserve estimates included in this study were estimated by performance methods, volumetric methods and comparisons with analogous wells, where applicable. The reserves estimated by the performance method utilized extrapolations of historical production data. These methods were deemed appropriate for the purpose of the report.
The reserves shown in this report are estimates only and should not be construed as exact quantities. Proved reserves are those quantities of oil and gas which, by analysis of engineering and geoscience data, can be estimated with reasonable certainty to be economically producible. If the reserves are recovered, the revenues therefrom and the costs related thereto could be more or less than the estimated amounts. Because of governmental policies and uncertainties of supply and demand, the sales rates, prices received for the reserves, and costs incurred in recovering such reserves may vary from assumptions made while preparing this report. Estimates of reserves may increase or decrease as a result of future operations, market conditions, or changes in regulations.
Prices and Costs
The hydrocarbon prices used in the report are averages from the first day of the month for the 12 months of 2009. These values are shown in the table below.
| Year |
Oil Price $/Bbl |
Gas Price $/MMbtu | ||||
| 2010 and later |
$ | 61.19 | $ | 3.866 | ||
Adjustments to the pricing shown were made at a lease level based on differentials to the posted prices due to hydrocarbon quality, transportation fees, contract terms, lease use, etc.
Operating costs used in the report were provided by GMX. Adjustments were made if applicable to reflect changing well counts in unitized fields. All operating costs were held constant over the life of the properties with no future escalation. These costs were not independently verified by MHA, but were checked for reasonableness.
Development costs used in the report were provided by GMX and are based on internal authority for expenditures (AFE’s) for the development projects or actual costs for similar
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development projects. These costs were not independently verified by MHA, but were checked for reasonableness.
Production taxes were applied per current regulatory standards, including credits given for Cotton Valley and Haynesville wells referred to as “high cost gas wells”. These are wells that are considered “tight formation gas wells” with drilling and completion costs in excess of the median value as defined by the State of Texas.
For the purposes of this report, MHA did not perform any field inspection of properties, nor did we examine the mechanical operation or condition of the wells and facilities. We have not investigated possible environmental liability related to the properties; therefore, our estimates do not include any costs due to such possible liability.
Abandonment costs net of salvage value were included in the runs, and were incurred at the end of the economic life of each well. No deductions were made for indirect costs such as loan repayments, interest expenses, and exploration and development prepayments.
Statement of Risk
The accuracy of reserve and economic evaluations is always subject to uncertainty. The magnitude of this uncertainty is generally proportional to the quantity and quality of data available for analysis. As a well matures and new information becomes available, revisions may be required which may either increase or decrease the previous reserve assignments. Sometimes these revisions may result not only in a significant change to the reserves and value assigned to a property, but also may impact the total company reserve and economic status. The reserves and forecasts contained in this report were based upon a technical analysis of the available data using accepted engineering principles. However, they must be accepted with the understanding that further information and future reservoir performance subsequent to the date of the estimate may justify their revision. It is MHA’s opinion that the estimated proven reserves and other reserve information as specified in this report are reasonable, and have been prepared in accordance with generally accepted petroleum engineering and evaluation principles, as set forth in the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserve Information, promulgated by the Society of Petroleum Engineers. Notwithstanding the aforementioned opinion, MHA makes no warranties concerning the data and interpretations of such data. In no event shall MHA be liable for any special or consequential damages arising from GMX’s use of MHA’s interpretation, reports, or services produced as a result of its work for GMX.
Neither MHA, nor any of our employees have any interest in the subject properties and neither the employment to do this work, nor the compensation, is contingent on our estimates of reserves for the properties in this report.
Sincerely
/s/ John W. Arsenault
John W. Arsenault
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