EXHIBIT 23.2

                                       Ryder Scott Letterhead




                                                   February 23, 2001





Mariner Energy, Inc.
580 WestLake Park Blvd., Suite 1300
Houston, Texas  77079

Gentlemen:

     At your request, we have prepared an estimate of the reserves, future
production, and income attributable to certain leasehold interests of Mariner
Energy, Inc. (Mariner) as of January 1, 2000. The subject properties are located
in the states of Louisiana, Mississippi, and Texas and in the federal waters
offshore Louisiana and Texas. The income data were estimated using the
Securities and Exchange Commission (SEC) guidelines for future price and cost
parameters.

     The estimated reserves and future income amounts presented in this report
are related to hydrocarbon prices. December 2000 hydrocarbon prices were used in
the preparation of this report as required by SEC guidelines; however, actual
future prices may vary significantly from December 2000 prices. Therefore,
volumes of reserves actually recovered and amounts of income actually received
may differ significantly from the estimated quantities presented in this report.
The results of this study are summarized below.


                                 SEC PARAMETERS
                     Estimated Net Reserves and Income Data
                         Certain Leasehold Interests of
                              Mariner Energy, Inc.
                             As of December 31, 2001
    ------------------------------------------------------------------------
<TABLE>
<CAPTION>

                                                                          Proved
                                ------------------------------------------------------------------------
                                            Developed                                        Total
                                ----------------------------------
                                  Producing        Non-Producing       Undeveloped           Proved
                                --------------     ---------------    ---------------    ---------------
<S>                              <C>                  <C>               <C>              <C>
Net Remaining Reserves
  Oil/Condensate - Barrels          5,432,500             106,360          6,845,509         12,384,469
  Plant Products - Barrels                473               1,068              1,385              2,926
  Gas - MMCF                           57,879               3,744             67,633            129,256

Income Data
  Future Gross Revenue           $790,720,274         $44,977,232       $923,036,533     $1,758,734,012
  Deductions                       88,931,338           4,823,796        230,140,007        323,895,141
                                 ------------         -----------       ------------     --------------

  Future Net Income (FNI)        $701,788,909         $40,153,436       $692,896,526     $1,434,838,871

  Discounted FNI @ 10%           $559,065,183         $33,057,342       $451,091,308     $1,043,213,833

</TABLE>

     Liquid hydrocarbons are expressed in standard 42 gallon barrels. All gas
volumes are sales gas expressed in millions of cubic feet (MMCF) at the official
temperature and pressure bases of the areas in which the gas reserves are
located.

     The future gross revenue is after the deduction of production taxes. The
deductions are comprised of the normal direct costs of operating the wells, ad
valorem taxes, recompletion costs, development costs, and certain abandonment
costs net of salvage. The future net income is before the deduction of state and
federal income taxes and general administrative overhead, and has not been
adjusted for outstanding loans that may exist nor does it include any adjustment
for cash on hand or undistributed income. No attempt was made to quantify or
otherwise account for any accumulated gas production imbalances that may exist.
Gas reserves account for approximately 52.8 percent, liquid hydrocarbon account
for approximately 47.1 percent, and plant product reserves account for the
remaining .1 percent of total future gross revenue from proved reserves.

     The discounted future net income shown above was calculated using a
discount rate of 10 percent per annum compounded monthly. Future net income was
discounted at four other discount rates which were also compounded monthly.
These results are shown on each estimated projection of future production and
income presented in a later section of this report and in summary form below.



<PAGE>




                                    Discounted Future Net Income
                                       As of January 1, 2000
                                   -------------------------------
               Discount Rate                   Total
                  Percent                      Proved
              -----------------    -------------------------------

                     15                     $187,191,557
                     20                     $168,461,313
                     25                     $153,163,797
                     30                     $140,291,355

     The results shown above are presented for your information and should not
be construed as our estimate of fair market value.

Reserves Included in This Report

     The proved reserves included herein conform to the definition as set forth
in the Securities and Exchange Commission's Regulation S-X Part 210.4-10 (a) as
clarified by subsequent Commission Staff Accounting Bulletins. The probable
reserves and possible reserves included herein conform to definitions of
probable and possible reserves approved by the Society of Petroleum Engineers
and the Society of Petroleum Evaluation Engineers. The definitions of proved,
probable, and possible reserves are included under the tab "Reserve Definitions
and Pricing Assumptions" in this report.


Estimates of Reserves

     In general, the reserves included herein were estimated by performance
methods or the volumetric method; however, other methods were used in certain
cases where characteristics of the data indicated such other methods were more
appropriate in our opinion. The reserves estimated by the performance method
utilized extrapolations of various historical data in those cases where such
data were definitive. Reserves were estimated by the volumetric method in those
cases where there were inadequate historical performance data to establish a
definitive trend or where the use of production performance data as a basis for
the reserve estimates was considered to be inappropriate.

     The reserves included in this report are estimates only and should not be
construed as being exact quantities. They may or may not be actually recovered,
and if recovered, the revenues therefrom and the actual costs related thereto
could be more or less than the estimated amounts. Moreover, estimates of
reserves may increase or decrease as a result of future operations.


<PAGE>



Future Production Rates

     Initial production rates are based on the current producing rates for those
wells now on production. Test data and other related information were used to
estimate the anticipated initial production rates for those wells or locations
which are not currently producing. If no production decline trend has been
established, future production rates were held constant, or adjusted for the
effects of curtailment where appropriate, until a decline in ability to produce
was anticipated. An estimated rate of decline was then applied to depletion of
the reserves. If a decline trend has been established, this trend was used as
the basis for estimating future production rates. For reserves not yet on
production, sales were estimated to commence at an anticipated date furnished by
Mariner.

     In general, we estimate that future gas production rates limited by
allowables or marketing conditions will continue to be the same as the average
rate for the latest available 12 months of actual production until such time
that the well or wells are incapable of producing at this rate. The well or
wells were then projected to decline at their decreasing delivery capacity rate.
Our general policy on estimates of future gas production rates is adjusted when
necessary to reflect actual gas market conditions in specific cases.

     The future production rates from wells now on production may be more or
less than estimated because of changes in market demand or allowables set by
regulatory bodies. Wells or locations which are not currently producing may
start producing earlier or later than anticipated in our estimates of their
future production rates.

Hydrocarbon Prices

     Mariner furnished us with prices in effect at December 31, 2000 and these
prices were held constant except for known and determinable escalations. In
accordance with Securities and Exchange Commission guidelines, changes in liquid
and gas prices subsequent to December 31, 2000, were not taken into account in
this report. Future prices used in this report are discussed in more detail
under the tab "Reserve Definitions and Pricing Assumptions" in this report.

Costs

     Operating costs for the leases and wells in this report are based on the
operating expense reports of Mariner and include only those costs directly
applicable to the leases or wells. When applicable, the operating costs include
a portion of general and administrative costs allocated directly to the leases
and wells under terms of operating agreements. No deduction was made for
indirect costs such as general administration and overhead expenses, loan
repayments, interest expenses, and exploration and development prepayments that
are not charged directly to the leases or wells.

     Development costs were furnished to us by Mariner and are based on
authorizations for expenditure for the proposed work or actual costs for similar
projects. The estimated net cost of abandonment after salvage was included for
properties where abandonment costs net of salvage are significant. The estimates
of the net abandonment costs furnished by Mariner were accepted without
independent verification.

     Current costs were held constant throughout the life of the properties.


<PAGE>



General

     Table A presents a one line summary of proved reserve and income data for
each of the subject properties which are ranked according to their future net
income discounted at 10 percent per year. Table B presents a one line summary of
gross and net reserves and income data for each of the subject properties. Table
C presents a one line summary of initial basic data for each of the subject
properties. Tables 1 through 369 present our estimated projection of production
and income by years beginning January 1, 2001, by state, field, and lease or
well.

     While it may reasonably be anticipated that the future prices received for
the sale of production and the operating costs and other costs relating to such
production may also increase or decrease from existing levels, such changes
were, in accordance with rules adopted by the SEC, omitted from consideration in
making this evaluation.

     The estimates of reserves presented herein were based upon a detailed study
of the properties in which Mariner owns an interest; however, we have not made
any field examination of the properties. No consideration was given in this
report to potential environmental liabilities which may exist nor were any costs
included for potential liability to restore and clean up damages, if any, caused
by past operating practices. Mariner has informed us that they have furnished us
all of the accounts, records, geological and engineering data, and reports and
other data required for this investigation. The ownership interests, prices, and
other factual data furnished by Mariner were accepted without independent
verification. The estimates presented in this report are based on data available
through December 2000.

     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 and future income for the subject
properties.

     This report was prepared for the exclusive use and sole benefit of Mariner
Energy, Inc. The data, work papers, and maps used in 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.



                                                   Timothy J. Torres, P.E.
                                                   Petroleum Engineer
JRW/sw


Approved:

___/s/ John R. Warner, P.E._______
John R. Warner, P.E.
Senior Vice President


<PAGE>


                             DEFINITIONS OF RESERVES




PROVED RESERVES  (SEC DEFINITION)

     Proved reserves of crude oil, condensate, natural gas, and natural gas
liquids are estimated quantities that geological and engineering data
demonstrate with reasonable certainty to be recoverable in the future from known
reservoirs under existing operating conditions, i.e., prices and costs as of the
date the estimate is made. Prices include consideration of changes in existing
prices provided only by contractual arrangements, but not on escalation based on
future conditions.

     Reservoirs are considered proved if economic producibility is supported by
either actual production or conclusive formation test. In certain instances,
proved reserves are assigned on the basis of a combination of core analysis and
electrical and other type logs which indicate the reservoirs are analogous to
reservoirs in the same field which are producing or have demonstrated the
ability to produce on a formation test. The area of a reservoir considered
proved includes (1) that portion delineated by drilling and defined by fluid
contacts, if any, and (2) the adjoining portions not yet drilled that can be
reasonably judged as economically productive on the basis of available
geological and engineering data. In the absence of data on fluid contacts, the
lowest known structural occurrence of hydrocarbons controls the lower proved
limit of the reservoir.

     Reserves that can be produced economically through the application of
improved recovery techniques are included in the proved classification when
these qualifications are met: (1) successful testing by a pilot project or the
operation of an installed program in the reservoir provides support for the
engineering analysis on which the project or program was based, and (2) it is
reasonably certain the project will proceed. Improved recovery includes all
methods for supplementing natural reservoir forces and energy, or otherwise
increasing ultimate recovery from a reservoir, including (1) pressure
maintenance, (2) cycling, and (3) secondary recovery in its original sense.
Improved recovery also includes the enhanced recovery methods of thermal,
chemical flooding, and the use of miscible and immiscible displacement fluids.

     Proved natural gas reserves are comprised of non-associated, associated and
dissolved gas. An appropriate reduction in gas reserves has been made for the
expected removal of natural gas liquids, for lease and plant fuel, and for the
exclusion of non-hydrocarbon gases if they occur in significant quantities and
are removed prior to sale. Estimates of proved reserves do not include crude
oil, natural gas, or natural gas liquids being held in underground or surface
storage.

     Proved reserves are estimates of hydrocarbons to be recovered from a given
date forward. They may be revised as hydrocarbons are produced and additional
data become available.



<PAGE>



                            Reserve Status Categories



     Reserve status categories define the development and producing status of
wells and/or reservoirs.

Proved Developed  (SEC Definition)

     Proved developed oil and gas reserves are reserves that can be expected to
be recovered through existing wells with existing equipment and operating
methods. Additional oil and gas expected to be obtained through the application
of fluid injection or other improved recovery techniques for supplementing the
natural forces and mechanisms of primary recovery should be included as "proved
developed reserves" only after testing by a pilot project or after the operation
of an installed program has confirmed through production response that increased
recovery will be achieved.

     Developed reserves may be subcategorized as producing or non-producing
using the SPE/SPEE Definitions:

     Producing

     Producing reserves are expected to be recovered from completion intervals
     open at the time of the estimate and producing. Improved recovery reserves
     are considered to be producing only after an improved recovery project is
     in operation.

     Non-Producing

     Non-producing reserves include shut-in and behind pipe reserves. Shut-in
     reserves are expected to be recovered from completion intervals open at the
     time of the estimate, but which had not started producing, or were shut-in
     for market conditions or pipeline connection, or were not capable of
     production for mechanical reasons, and the time when sales will start is
     uncertain. Behind pipe reserves are expected to be recovered from zones
     behind casing in existing wells, which will require additional completion
     work or a future recompletion prior to the start of production.

     Proved Undeveloped (SEC Definition)

     Proved undeveloped oil and gas reserves are reserves 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. Reserves
     on undrilled acreage shall be limited to those drilling units offsetting
     productive units that are reasonably certain of production when drilled.
     Proved reserves for other undrilled units can be claimed only where it can
     be demonstrated with certainty that there is continuity of production from
     the existing productive formation. Estimates for proved undeveloped
     reserves are attributable to any acreage for which an application of fluid
     injection or other improved technique is contemplated, only when such
     techniques have been proved effective by actual tests in the area and in
     the same reservoir.




<PAGE>



                         HYDROCARBON PRICING PARAMETERS

                  Securities and Exchange Commission Parameters



Oil and Condensate

     Mariner furnished us with oil and condensate prices in effect at December
31, 1999 and these prices were held constant to depletion of the properties. In
accordance with Securities and Exchange Commission guidelines, changes in liquid
prices subsequent to December 31, 1999 were not considered in this report.

Plant Products

     Mariner furnished us with plant product prices in effect at December 31,
1999 and these prices were held constant to depletion of the properties.

Gas

     Mariner furnished us with gas prices in effect at December 31, 1999 and
with its forecasts of future gas prices which take into account SEC guidelines,
current spot market prices, contract prices, and fixed and determinable price
escalations where applicable. In accordance with SEC guidelines, the future gas
prices used in this report make no allowances for future gas price increases
which may occur as a result of inflation nor do they make any allowance for
seasonal variations in gas prices which may cause future yearly average gas
prices to be somewhat lower than December 31, 1999 gas prices. For gas sold
under contract, the contract gas price including fixed and determinable
escalations, exclusive of inflation adjustments, was used until the contract
expires and then was adjusted to the current market price for the area and held
at this adjusted price to depletion of the reserves.