Exhibit 10.69
[RYDER SCOTT COMPANY PETROLEUM ENGINEERS LETTERHEAD]
October 8, 1999
ABM AMRO Bank NV
Oil and Gas Group
101 Moorgate
London EC2M 6SB United Kingdom
Attn: Mr. Paul Matthews
Shell Capital Services Limited
Shell Centre
London SE1 7NA United Kingdom
Attn: Mr. Mark Turner
Gentlemen:
At your request, Ryder Scott Company, L.P. has prepared an update to the
reserve estimates we prepared in 1995 for the Karakuduk Field located in The
Republic of Kazakhstan. This estimate incorporates additional data that has been
developed since our original estimate. It is our opinion that none of this
additional data provides a basis for either increasing or decreasing our
original estimate. A summary of our reserve estimates are presented in the
following tables.
Estimated Gross Reserves
Attributable to the Karakuduk Field
Proved
Formation (M bbls)
---------------------- --------------------
J1 Lower 61,786
J2 257
J4 500
J5 1,199
J8 9,198
J9 950
------
Total 73,890
Probable
Formation (M bbls)
---------------------- --------------------
J1 Lower 30,893(1)
J1 Upper 2,777
J2 3,606
J3 7,225
J4 4,540
J8 4,599(1)
------
Total 53,640
(1) Pressure Maintenance-Water injection reserves
Chaparral Resources, Inc.
October 8, 1999
Page 2
Review Procedure
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The first step was to review our 1995 analysis. At that point, the
following additional data was reviewed.
Production data from well #10, #21 and #101
Well log data from well #101
Pressure build-up test and analysis from well #10 and well #101
Production log (spinner survey) from well #10
The log data from new well #101 was reviewed for both formation tops and
pay thickness. This was then compared to the geologic interpretation that was
used as a basis for my volumetric calculations. In my opinion, the differences
were not significant enough to warrant a revision to the geology at this time.
This data plus a review of the other data listed above was not sufficient to
warrant a revision, either upward or downward to our prior estimates.
It should be noted that as of October 1, 1999, the cumulative production
from the field is 352.1 thousand barrels.
The pressure build-up on well #101 shows significant damage and when funds
are available, a stimulation treatment should yield a productive increase. Well
#21 appears to be damaged but a pressure build-up test cannot be run because of
wellhead problems.
Reserve Estimates
- -----------------
The original reserve estimates of January 13, 1995 were based on a
volumetric analysis and assignment of recover factors for primary and
incremental pressure maintenance reserves and have not changed. A copy of this
letter is attached. The data and assumptions utilized in these calculations were
contained in that letter.
The reserves presented herein are estimates only and should not be
construed as being exact quantities. Moreover, estimates of reserves may
increase of decrease as a result of future operations.
The proved and probable reserves, which are attributable to the wells and
locations reviewed by Ryder Scott, conform to the definitions approved by the
Society of Petroleum Engineers and the World Petroleum Congress, except that no
economic evaluations have been performed at this time. It is assumed, based on
current development activity in Kazakhstan, that economic development of these
reserves can be achieved. Our definitions of proved and probable reserves
follows.
PROVED RESERVES
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Proved reserves are those quantities of petroleum which, by analysis of
geological and engineering data, can be estimated with reasonable certainty to
be commercially recoverable, from a given date forward, from known reservoirs
and under current economic conditions, operating methods, and government
regulations. Proved reserves can be categorized as developed or undeveloped.
Chaparral Resources, Inc.
October 8, 1999
Page 3
If deterministic methods are used, the term reasonable certainty is
intended to express a high degree of confidence that the quantities will be
recovered. If probabilistic methods are used, there should be at least a 90
percent probability that the quantities actually recovered will equal or exceed
the estimate.
Establishment of current economic conditions should include relevant
historical petroleum prices and associated costs and may involve an averaging
period that is consistent with the purpose of the reserve estimate, appropriate
contract obligations, corporate procedures, and government regulations involved
in reporting these reserves.
In general, reserves are considered proved if the commercial producibility
of the reservoir is supported by actual production or formation tests. In this
context, the term proved refers to the actual quantities of petroleum reserves
and not just the productivity of the well or reservoir. In certain cases, proved
reserves may be assigned on the basis of well logs and/or core analysis that
indicate the subject reservoir is hydrocarbon bearing and is analogous to
reservoirs in the same area that are producing or have demonstrated the ability
to produce on formation tests.
The area of the reservoir considered as proved includes (1) the area
delineated by drilling and defined by fluid contacts, if any, and (2) the
undrilled portions of the reservoir that can reasonably be judged as
commercially productive on the basis of available geological and engineering
data. In the absence of data on fluid contacts, the lowest known occurrence of
hydrocarbons controls the proved limit unless otherwise indicated by definitive
geological, engineering or performance data.
Reserves may be classified as proved if facilities to process and transport
those reserves to market are operational at the time of the estimate or there is
a reasonable expectation that such facilities will be installed. Reserves in
undeveloped locations may be classified as proved undeveloped provided (1) the
locations are direct offsets to wells that have indicated commercial production
in the objective formation, (2) it is reasonably certain such locations are
within the known proved productive limits of the objective formation, (3) the
locations conform to existing well spacing regulations where applicable, and (4)
it is reasonably certain the locations will be developed. Reserves from other
locations are categorized as proved undeveloped only where interpretations of
geological and engineering data from wells indicate with reasonable certainty
that the objective formation is laterally continuous and contains commercially
recoverable petroleum at locations beyond direct offsets.
Reserves which are to be produced through the application of established
improved recovery methods are included in the proved classification when (1)
successful testing by a pilot project or favorable response of an installed
program in the same or an analogous reservoir with similar rock and fluid
properties provides support for the analysis on which the project was based, and
(2) it is reasonably certain that the project will proceed. Reserves to be
recovered by improved recovery methods that have yet to be established through
commercially successful applications are included in the proved classification
only (1) after a favorable production response from the subject reservoir from
either (a) a representative pilot or (b) an installed program where the response
provides support for the analysis on which the project is based and (2) it is
reasonably certain the project will proceed.
Probable Reserves
- -----------------
Probable reserves are those unproved reserves which analysis of geological
and engineering data suggests are more likely than not to be recoverable. In
this context, when probabilistic methods are used, there should be at least a 50
percent probability that the quantities actually recovered will equal or exceed
the sum of estimated proved plus probable reserves.
Chaparral Resources, Inc.
October 8, 1999
Page 4
In general, probable reserves may include (1) reserves anticipated to be
proved by normal step-out drilling where sub-surface control is inadequate to
classify these reserves as proved, (2) reserves in formations that appear to be
productive based on well log characteristics but lack core data or definitive
tests and which are not analogous to producing or proved reserves in the area,
(3) incremental reserves attributable to infill drilling that could have been
classified as proved if closer statutory spacing had been approved at the time
of the estimate, (4) reserves attributable to improved recovery methods that
have been established by repeated commercially successful applications when (a)
a project or pilot is planned but not in operation and (b) rock, fluid, and
reservoir characteristics appear favorable for commercial application, (5)
reserves in an area of the formation that appears to be separated from the
proved area by faulting and the geologic interpretation indicates the subject
area is structurally higher than the proved area, (6) reserves attributable to a
future workover, treatment, re-treatment, change of equipment, or other
mechanical procedures, where such procedure has not been proved successful in
wells which exhibit similar behavior in analogous reservoirs, and (7)
incremental reserves in proved reservoirs where an alternative interpretation of
performance or volumetric data indicates more reserves than can be classified as
proved.
General
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Neither we nor any of our employees have any interest in the subject
properties and neither the employment to make this study nor the compensation is
contingent on our estimates of reserves for the properties which were reviewed.
This report was prepared for the exclusive use and sole benefit of ABM AMRO
Bank NV, Shell Capital Services Limited and Chaparral Resources, Inc. The data,
work papers, and maps used in the preparation of this report are available for
examination by authorized parties in our offices. Please contact us if we can be
of further service.
Very truly yours,
RYDER SCOTT COMPANY, L.P.
/s/ Larry T. Nelms
----------------------------------
Larry T. Nelms
Senior Vice President
Cc: Chaparral Resources, Inc.
LTN:ph