Attached files
file | filename |
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10-K - FORM 10-K - PHX MINERALS INC. | d78254e10vk.htm |
EX-23 - EX-23 - PHX MINERALS INC. | d78254exv23.htm |
EX-21 - EX-21 - PHX MINERALS INC. | d78254exv21.htm |
EX-32.2 - EX-32.2 - PHX MINERALS INC. | d78254exv32w2.htm |
EX-31.1 - EX-31.1 - PHX MINERALS INC. | d78254exv31w1.htm |
EX-32.1 - EX-32.1 - PHX MINERALS INC. | d78254exv32w1.htm |
EX-31.2 - EX-31.2 - PHX MINERALS INC. | d78254exv31w2.htm |
EXHIBIT 99
DeGolyer and MacNaughton 5001
Spring Valley Road Suite 800 East
Dallas, Texas 75244
Spring Valley Road Suite 800 East
Dallas, Texas 75244
This is a digital representation of a DeGolyer and MacNaughton report.
Each file contained herein is intended to be a manifestation of certain data in the subject report
and as such is subject to the definitions, qualifications, explanations, conclusions, and other
conditions thereof. The information and data contained in each file may be subject to
misinterpretation; therefore, the signed and bound copy of this report should be considered the
only authoritative source of such information.
(81)
DeGolyer and MacNaughton
500 I Spring Valley Road
Suite 800 East
Dallas, Texas 75244
500 I Spring Valley Road
Suite 800 East
Dallas, Texas 75244
September 30, 2010
Panhandle Oil and Gas Inc.
5400 North Grand Blvd.
Grand Centre Building, Suite 300
Oklahoma City, Oklahoma 73112
5400 North Grand Blvd.
Grand Centre Building, Suite 300
Oklahoma City, Oklahoma 73112
Ladies and Gentlemen:
Pursuant to your request, we have prepared estimates of the extent and value of the net proved
crude oil, condensate, and natural gas reserves, as of September 30, 2010, of certain properties
owned by Panhandle Oil and Gas Inc. (Panhandle) and Wood Oil Company (Wood), a wholly owned
subsidiary of Panhandle. The properties appraised consist of working and royalty interests located
in the states of Arkansas, Kansas, New Mexico, Oklahoma, and Texas. Panhandle and Wood have
represented that these properties account for 100 percent of proved reserves.
Estimates of proved reserves presented in this report have been prepared in compliance with
the regulations promulgated by the United States Securities and
Exchange Commission (SEC). These
reserves definitions are discussed in detail under the Definition of Reserves heading of this
letter.
Reserves included herein are expressed as gross and net reserves. Gross reserves are defined
as the total estimated petroleum to be produced from these properties after September 30, 2010.
Net reserves are defined as that portion of the gross reserves attributable to the interests owned
by Panhandle and Wood after deducting all royalties and interests owned by others. Gas quantities
shown herein are sales gas quantities and are expressed at a temperature base of 60 degrees
Fahrenheit and at the legal pressure base of the state in which the interest is located. Sales gas
is defined as the total gas to be produced from the reservoirs, measured at the point of delivery,
after reduction for fuel usage, flare, and shrinkage resulting from field separation and
processing. Condensate reserves estimated herein are those to be recovered by normal field
separation.
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Values of proved reserves shown herein are expressed in terms of estimated future gross
revenue, future net revenue, and present worth of future net revenue. 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 investments from 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 10 percent per annum over the expected period of realization.
Estimates of oil, condensate, and natural 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 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.
Data used in this report were obtained from Panhandle and Wood, from records on file with the
appropriate regulatory agencies, and from public sources. Additionally, this information includes
data supplied by Petroleum Information/Dwights LLC; Copyright 2010 Petroleum Information/Dwights
LLC. In the preparation of this report we have relied, without independent verification,
upon such information furnished by Panhandle with respect to property interests appraised,
production from such properties, current costs of operation and development, current prices for
production, agreements relating to current and future operations and sale of 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.
Methodology and Procedures
Estimates of reserves were prepared by the use of standard 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.
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When applicable, the volumetric method was used to estimate the original oil in place (OOIP)
and the original gas in place (OGIP). Structure 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 or to
the limit of the production licenses as appropriate.
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 4 10(a) (1)(32) of Regulation S-X 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:
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Proved
ail 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, 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:
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(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 he 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.
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
oil and gas 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
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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.
Primary Economic Assumptions
Revenue values in this report were estimated using the initial prices and costs specified by
Panhandle and Wood. Future prices were estimated using guidelines established by the SEC and the
Financial Accounting Standards Board (FASB). The initial and future prices used in this report are
adjusted to prices on September 30, 2010. The following economic assumptions were used for
estimating existing and future prices and costs:
Oil, Condensate, and Natural Gas Prices
Oil and condensate price differentials for each property were provided by
Panhandle and Wood. The prices were calculated using these differentials
to a posted WTI price of $77.63 per barrel and were held constant for the
lives of the properties. The WTI price of $77.63 is the 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 September 30, 2010.
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Gas price differentials far each property were provided by Panhandle and
Wood. The prices were calculated using these differentials to a Henry Hub
price of $4.49 per million British thermal units (MMBtu) and were held
constant for the lives of the properties. The Henry Hub gas price of $4.49
per MMBtu is the 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 September 30, 2010.
The weighted average prices over the lives of the properties were $69.23
per barrel of oil and $4.33 per thousand cubic feet of gas.
Operating Expenses and Capital Costs
Estimates of operating expenses and capital costs based on current costs
were used for the lives of the properties with no increases in the future
based on inflation. In certain cases, future costs, either higher or lower
than current costs, may have been used because of anticipated changes in
operating conditions. Future capital costs were estimated using 2010
values and were not adjusted for inflation.
While the oil and gas industry may be subject to regulatory changes from time to time that
could affect an industry participants ability to recover its oil and gas reserves, we are not
aware of any such governmental actions which would restrict the recovery of the September 30, 2010,
estimated oil and gas volumes. The reserves estimated in this report can be produced under current
regulatory guidelines.
Summary Reserves and Revenues
The estimates of the combined net proved reserves attributable to Panhandle and Wood from the
properties appraised, as of September 30, 2010, are summarized as follows, expressed in thousands
of barrels (Mbbl) and millions of cubic feet (MMcf):
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Oil and | Sales | |||||||
Condensate | Gas | |||||||
(Mbbl) | (MMcf) | |||||||
Proved |
||||||||
Developed Producing |
848 | 56,456 | ||||||
Developed Non producing |
14 | 888 | ||||||
Undeveloped |
63 | 40,826 | ||||||
Total Proved |
925 | 98,170 |
The estimated future revenue to be derived from the production and sale of the combined proved
reserves, as of September 30, 2010, of the properties appraised is summarized as follows, expressed
in thousands of dollars (M$):
Proved | ||||||||||||||||
Developed | Developed | Total | ||||||||||||||
Producing | Nonproducing | Undeveloped | Proved | |||||||||||||
Future Gross Revenue,
M$ |
303,218 | 5,035 | 181,439 | 489,692 | ||||||||||||
Production & Ad
Valorem Taxes. M$ |
21,394 | 362 | 8,484 | 30,240 | ||||||||||||
Operating
Expenses, M$ |
81,090 | 1.131 | 36,267 | 118,488 | ||||||||||||
Capital
Costs, M$ |
0 | 489 | 52,487 | 52,976 | ||||||||||||
Future Net
Revenue, M$ |
200,734 | 3,053 | 84,201 | 287,988 | ||||||||||||
Present Worth at 10
Percent, M$ |
103,343 | 685 | 21,960 | 125,988 |
Note: Future income taxes have not been taken into account in the preparation of these estimates. |
In our opinion, the information relating to estimated proved reserves, estimated future net
revenue from proved reserves, and present worth of estimated future net revenue from proved
reserves of oil, condensate, 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 4-10(a) (1)-(32) of
Regulation S-X and Rules 302(b),
1201, 1202(a) (1), (2), (3), (4), (8), and 1203(a) of Regulation S-K of the Securities and Exchange
Commission; 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.
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To the extent the above-enumerated rules, regulations, and statements require determinations
of an accounting or legal nature, we are necessarily unable to express an opinion as to whether
the above-described information is in accordance therewith or sufficient therefor.
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 Panhandle. Our fees
were not contingent on the results of our evaluation. This letter report has been prepared at the
request of Panhandle. DeGolyer and MacNaughton has used all assumptions, data, methods, and
procedures that it considers necessary to prepare this report.
Submitted, |
||||
(DeGOLYER and MacNAUGHTON) | ||||
DeGOLYER and MacNAUGHTON | ||||
Texas Registered Engineering Firm F-716 | ||||
/s/ Paul J. Szatkowski, PE | ||||
Paul J. Szatkowski, P.E. Senior Vice President DeGolyer and MacNaughton |
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 letter report addressed to Panhandle Oil and Gas Inc. dated September 30, 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 the American Association of Petroleum Geologists; and that I have in excess of 36 years of experience in the oil and gas reservoir studies and reserves evaluations. | ||
Signed: September 30, 2010 |
/s/ Paul J. Szatkowski, PE | ||||
Paul J. Szatkowski, P.E. Senior Vice President DeGolyer and MacNaughton |