Attached files
| file | filename |
|---|---|
| EX-99.4 - EX-99.4 - COMSTOCK RESOURCES INC | exhibit994.htm |
| EX-99.3 - EX-99.3 - COMSTOCK RESOURCES INC | exhibit993.htm |
| EX-99.1 - EX-99.1 - COMSTOCK RESOURCES INC | exhibit991.htm |
| EX-32.2 - EX-32.2 - COMSTOCK RESOURCES INC | crk-20201231x10kexx322.htm |
| EX-32.1 - EX-32.1 - COMSTOCK RESOURCES INC | crk-20201231x10kexx321.htm |
| EX-31.2 - EX-31.2 - COMSTOCK RESOURCES INC | crk-20201231x10kexx312.htm |
| EX-31.1 - EX-31.1 - COMSTOCK RESOURCES INC | crk-20201231x10kexx311.htm |
| EX-23.3 - EX-23.3 - COMSTOCK RESOURCES INC | exhibit233.htm |
| EX-23.2 - EX-23.2 - COMSTOCK RESOURCES INC | exhibit232.htm |
| EX-23.1 - EX-23.1 - COMSTOCK RESOURCES INC | exhibit231.htm |
| EX-21 - EX-21 - COMSTOCK RESOURCES INC | exhibit21.htm |
| EX-10.20 - EX-10.20 - COMSTOCK RESOURCES INC | exhibit1020.htm |
| EX-10.7 - EX-10.7 - COMSTOCK RESOURCES INC | exhibit107.htm |
| EX-4.12 - EX-4.12 - COMSTOCK RESOURCES INC | exhibit412.htm |
| 10-K - 10-K - COMSTOCK RESOURCES INC | crk-20201231.htm |
Exhibit 99.2
February 5, 2021
Mr. David Terry
Comstock Resources, Inc.
5300 Town & Country Boulevard
Frisco, Texas 75034
Dear Mr. Terry:
In accordance with your request, we have audited the estimates prepared by Comstock Resources, Inc. (Comstock), as of December 31, 2020, of the proved reserves and future revenue to the Comstock interest in certain gas properties located in Louisiana and Texas. It is our understanding that the proved reserves estimates shown herein constitute approximately 95 percent of all proved reserves owned by Comstock. We have examined the estimates with respect to reserves quantities, reserves categorization, future producing rates, future net revenue, and the present value of such future net revenue, using the definitions set forth in U.S. Securities and Exchange Commission (SEC) Regulation S-X Rule 4-10(a). The estimates of reserves and future revenue have been prepared in accordance with the definitions and regulations of the SEC and, with the exception of the exclusion of future income taxes, conform to the FASB Accounting Standards Codification Topic 932, Extractive Activities—Oil and Gas. We completed our audit on or about the date of this letter. This report has been prepared for Comstock's use in filing with the SEC; in our opinion the assumptions, data, methods, and procedures used in the preparation of this report are appropriate for such purpose.
The following table sets forth Comstock's estimates of the net reserves and future net revenue, as of December 31, 2020, for the audited properties:
| Net Reserves | Future Net Revenue (M$) | |||||||||||||||||||||||||
Gas(1) | Condensate | Present Worth | ||||||||||||||||||||||||
| Category | (MMCF) | (MBBL) | Total | at 10% | ||||||||||||||||||||||
| Proved Developed Producing | 1,764,493.1 | 85.7 | 1,875,676.2 | 1,205,436.1 | ||||||||||||||||||||||
| Proved Developed Non-Producing | 5,952.4 | 0.0 | 5,493.2 | 2,451.2 | ||||||||||||||||||||||
| Proved Undeveloped | 3,595,587.9 | 0.0 | 2,079,507.9 | 659,617.1 | ||||||||||||||||||||||
| Total Proved | 5,366,033.4 | 85.7 | 3,960,677.3 | 1,867,504.4 | ||||||||||||||||||||||
(1) Gas reserves are inclusive of natural gas liquids (NGL) equivalent volumes, determined using the ratio of 6 MCF of gas to 1 barrel of NGL.
Gas volumes are expressed in millions of cubic feet (MMCF) at standard temperature and pressure bases. Condensate volumes are expressed in thousands of barrels (MBBL); a barrel is equivalent to 42 United States gallons. Gas plus NGL equivalent volumes shown in this report are expressed in millions of cubic feet equivalent (MMCFE), determined using the ratio of 6 MCF of gas to 1 barrel of NGL.
When compared on a lease-by-lease basis, some of the estimates of Comstock are greater and some are less than the estimates of Netherland, Sewell & Associates, Inc. (NSAI). However, in our opinion the estimates shown herein of Comstock's reserves and future revenue are reasonable when aggregated at the proved level and have been prepared in accordance with the Standards Pertaining to the Estimating and Auditing of Oil and Gas
Reserves Information promulgated by the Society of Petroleum Engineers (SPE Standards). Additionally, these estimates are within the recommended 10 percent tolerance threshold set forth in the SPE Standards. We are satisfied with the methods and procedures used by Comstock in preparing the December 31, 2020, estimates of reserves and future revenue, and we saw nothing of an unusual nature that would cause us to take exception with the estimates, in the aggregate, as prepared by Comstock.
Reserves categorization conveys the relative degree of certainty; reserves subcategorization is based on development and production status. The estimates of reserves and future revenue included herein have not been adjusted for risk. Comstock's estimates do not include probable or possible reserves that may exist for these properties, nor do they include any value for undeveloped acreage beyond those tracts for which undeveloped reserves have been estimated.
Prices used by Comstock are based on the 12-month unweighted arithmetic average of the first-day-of-the-month price for each month in the period January through December 2020. For gas volumes, the average Henry Hub spot price of $1.99 per MMBTU is adjusted for energy content, transportation fees, and market differentials; when applicable, gas prices have been adjusted to include the value for NGL. For condensate volumes, the average NYMEX West Texas Intermediate (WTI) price of $39.57 per barrel is adjusted for quality and market differentials. As a reference, for the same time period the average WTI spot price was $39.54 per barrel. All prices are held constant throughout the lives of the properties. The average adjusted product prices weighted by production over the remaining lives of the properties are $1.722 per MCF of gas and $32.56 per barrel of condensate.
Operating costs used in this report are based on operating expense records of Comstock. For the nonoperated properties, these costs include the per-well overhead expenses allowed under joint operating agreements along with estimates of costs to be incurred at and below the district and field levels. As requested, operating costs for the operated properties are limited to direct lease- and field-level costs and Comstock's estimate of the portion of headquarters general and administrative overhead expenses necessary to operate the properties. Operating costs have been divided into per-well costs and per-unit-of-production costs and are not escalated for inflation. Capital costs used by Comstock are based on authorizations for expenditure and actual costs from recent activity. Capital costs are included as required for workovers, new development wells, and production equipment. Abandonment costs used are Comstock's estimates of the costs to abandon the wells and production facilities, net of any salvage value. Operating, capital, and abandonment costs are not escalated for inflation.
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; probable and possible reserves are those additional reserves which are sequentially less certain to be recovered than proved reserves. Estimates of reserves may increase or decrease as a result of market conditions, future operations, changes in regulations, or actual reservoir performance. In addition to the primary economic assumptions discussed herein, estimates of Comstock and NSAI are based on certain assumptions including, but not limited to, that the properties will be developed consistent with current development plans as provided to us by Comstock, that the properties will be operated in a prudent manner, that no governmental regulations or controls will be put in place that would impact the ability of the interest owner to recover the reserves, and that projections of future production will prove consistent with actual performance. 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 these estimates.
Our audit consisted primarily of substantive testing, wherein we conducted a detailed review of all properties. In the conduct of our audit, we have not independently verified the accuracy and completeness of information and data furnished by Comstock with respect to ownership interests, oil and gas production, well test data, historical
costs of operation and development, product prices, or any agreements relating to current and future operations of the properties and sales of production. However, if in the course of our examination something came to our attention that brought into question the validity or sufficiency of any such information or data, we did not rely on such information or data until we had satisfactorily resolved our questions relating thereto or had independently verified such information or data. Our audit did not include a review of Comstock's overall reserves management processes and practices.
We used standard engineering and geoscience methods, or a combination of methods, including performance analysis, volumetric analysis, and analogy, that we considered to be appropriate and necessary to establish the conclusions set forth herein. As in all aspects of oil and gas evaluation, there are uncertainties inherent in the interpretation of engineering and geoscience data; therefore, our conclusions necessarily represent only informed professional judgment.
Supporting data documenting this audit, along with data provided by Comstock, are on file in our office. The technical persons primarily responsible for conducting this audit meet the requirements regarding qualifications, independence, objectivity, and confidentiality set forth in the SPE Standards. Matthew T. Dalka, a Licensed Professional Engineer in the State of Texas, has been practicing consulting petroleum engineering at NSAI since 2013 and has over 7 years of prior industry experience. William J. Knights, a Licensed Professional Geoscientist in the State of Texas, has been practicing consulting petroleum geoscience at NSAI since 1991 and has over 10 years of prior industry experience. We are independent petroleum engineers, geologists, geophysicists, and petrophysicists; we do not own an interest in these properties nor are we employed on a contingent basis.
Sincerely,
| NETHERLAND, SEWELL & ASSOCIATES, INC. | |||||
| Texas Registered Engineering Firm F-2699 | |||||
| By: | /s/ C.H. (Scott) Rees III | ||||
| C.H. (Scott) Rees III, P.E. | |||||
| Chairman and Chief Executive Officer | |||||
| By: | /s/ Matthew T. Dalka | ||||
| Matthew T. Dalka, P.E. 125306 | |||||
| Vice President | |||||
| Date Signed: February 5, 2021 | |||||
| By: | /s/ William J. Knights | ||||
| William J. Knights, P.G. 1532 | |||||
| Vice President | |||||
| Date Signed: February 5, 2021 | |||||
Please be advised that the digital document you are viewing is provided by Netherland, Sewell & Associates, Inc. (NSAI) as a convenience to our clients. The digital document is intended to be substantively the same as the original signed document maintained by NSAI. The digital document is subject to the parameters, limitations, and conditions stated in the original document. In the event of any differences between the digital document and the original document, the original document shall control and supersede the digital document. | ||||||||||||||