1100 LOUISIANA        SUITE 3800    HOUSTON, TEXAS 77002-5218        TELEPHONE (713) 651-9191     FAX (713) 651-0849



March 6, 2002



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 December 31, 2001. The subject properties are
located in the states of 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 2001 hydrocarbon prices were used in the preparation of this report as required by SEC guidelines; however,
actual future prices may vary significantly from December 2001 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 ofMariner Energy, Inc.
As of December 31, 2001
|--------------------------------------------------------------------------------------------------------------------------------
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|                                                                                                                                
|                                                                                                                                
|Net Remaining Reserves                                                                                                          
|Oil/Condensate - Barrels                                                                                                        
|Gas - MMCF                                                                                                                      
|Income Data                                                                                                                     
|Future Gross Revenue                                                                                                            
|Deductions                                                                                                                      
|                                                                                                                                
|Future Net Income (FNI)                                                                                                         
|Discounted FNI @ 10%                                                                                                            



|                         | Probable   
|------------------------ | -----------
|                         |            
|                         | Developed  
|                         |            
|                         | Producing  
|                         |            
|Net Remaining Reserves  
|Oil/Condensate - Barrels | 1,525,311  
|Gas - MMCF               | 1,419      
|Income Data             
|Future Gross Revenue     | $24,158,461
|Deductions               | 3,706,856  
|                         |            
|Future Net Income (FNI)  | $20,451,605
|Discounted FNI @ 10%     | $16,911,547



|                         | Possible                  
|------------------------ | --------------------------
|                         |                           
|                         | Developed    Non-Producing
|                         |                           
|Net Remaining Reserves  
|Oil/Condensate - Barrels | 10,339                    
|Gas - MMCF               | 3,522                     
|Income Data             
|Future Gross Revenue     | $9,384,646                
|Deductions               | 1,599,032                 
|                         |                           
|Future Net Income (FNI)  | $7,785,614                
|Discounted FNI @ 10%     | $5,587,105                

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 74 percent and liquid
hydrocarbon account for approximately 26 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 three 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 as follows.

|                       | Discounted Future Net IncomeAs of December 31, 2001
|---------------------- | ---------------------------------------------------
|                       |                                                    
|Discount Rate  Percent | Total        Proved                                
|                       |                                                    
|15                     | $203,662,724                                       
|20                     | $180,638,471                                       
|25                     | $161,389,739                                       

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" in this report.

     We have included probable and possible reserves and income in this report at the request of Mariner. These data
are for Mariner's information only and should not be included in reports to the SEC according to the SEC guidelines. The
probable reserves are less certain to be recovered than the proved reserves and reserves classified as possible are less
certain to be recovered than those in the probable category. The reserves and income quantities attributable to the
different reserve classifications that are included herein have not been adjusted to reflect the varying degrees of risk
associated with them and thus are not comparable.

     Because of the direct relationship between volumes of proved undeveloped reserves and development plans, we
include in the proved undeveloped category only reserves assigned to undeveloped locations that we have been assured will
definitely be drilled.

     The proved, probable and possible developed non-producing reserves included herein are comprised of shut-in and
behind pipe categories. The various reserve status categories are defined under the tab "Reserve Definitions" 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.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.

     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 hydrocarbon prices in effect at December 31, 2001 and with its forecasts of future
prices which take into account SEC and Financial Accounting Standards Board (FASB) rules, current market prices, contract
prices, and fixed and determinable price escalations where applicable.

     In accordance with FASB Statement No. 69, December 31, 2001 market prices were determined using the daily oil
price or daily gas sales price ("spot price") adjusted for oilfield or gas gathering hub and wellhead price differences
(e.g. grade, transportation, gravity, sulfur and BS&W) as appropriate. Also in accordance with SEC and FASB
specifications, changes in market prices subsequent to December 31, 2001 were not considered 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. In the East Breaks 579 field, offshore Louisiana, there is a $462,500 per month loan repayment fee built into the
lease operating expense for the first 60 months of the field life. This fee is paid to El Paso Energy for their
financing a portion of the field pipeline expenses.

     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.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 377 present our estimated projection of
production and income by years beginning January 1, 2002, 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 2001.

     Mariner has assured us of their intent and ability to proceed with the development activities included in this
report, and that they are not aware of any legal, regulatory or political obstacles that would significantly alter their
plans.

     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
|---------------------------------------------------------- | ------------------------------------------------------------------------------------
|TJT/swApproved:                                           
|                                                          
|John R. Warner, P.E.Executive Vice President-International



MARINER ENERGY, INC.

Estimated
Future Reserves and Income
Attributable to Certain
Leasehold Interests
(SEC Parameters)
As of
December 31, 2001



PETROLEUM RESERVES DEFINITIONS
SECURITIES AND EXCHANGE COMMISSION

INTRODUCTION

     Reserves are those quantities of petroleum which are anticipated to be commercially recovered from known
accumulations from a given date forward. All reserve estimates involve some degree of uncertainty. The uncertainty
depends chiefly on the amount of reliable geologic and engineering data available at the time of the estimate and the
interpretation of these data. The relative degree of uncertainty may be conveyed by placing reserves into one of two
principal classifications, either proved or unproved. Unproved reserves are less certain to be recovered than proved
reserves and may be further sub-classified as probable and possible reserves to denote progressively increasing
uncertainty in their recoverability. It should be noted that Securities and Exchange Commission Regulation S-K prohibits
the disclosure of estimated quantities of probable or possible reserves of oil and gas and any estimated value thereof in
any documents publicly filed with the Commission.

     Reserves estimates will generally be revised as additional geologic or engineering data become available or as
economic conditions change. Reserves do not include quantities of petroleum being held in inventory, and may be reduced
for usage or processing losses if required for financial reporting.

     Reserves may be attributed to either natural energy or improved recovery methods. Improved recovery methods
include all methods for supplementing natural energy or altering natural forces in the reservoir to increase ultimate
recovery. Examples of such methods are pressure maintenance, cycling, waterflooding, thermal methods, chemical flooding,
and the use of miscible and immiscible displacement fluids. Other improved recovery methods may be developed in the
future as petroleum technology continues to evolve.PROVED RESERVES (SEC DEFINITIONS)


     Securities and Exchange Commission Regulation S-X Rule 4-10 paragraph (a) defines proved reserves as follows:Proved oil and gas reserves.Proved oil and gas reserves are the estimated quantities of crude oil, natural gas, and
natural gas liquids which geological and engineering data demonstrate with reasonable certainty to be recoverable in
future years from known reservoirs under existing economic and 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 escalations based upon future conditions.

| | (i)   Reservoirs are considered proved if economic producibility is supported by either actual production or
conclusive formation test. The area of a reservoir considered proved includes:
| | -------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------

| | (A)    that portion delineated by drilling and defined by gas-oil and/or oil-water contacts, if any; and                                                                                                                                                                                                                                      
| | ----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
| | (B)     the immediately adjoining portions not yet drilled, but which can be reasonably judged as economically
productive on the basis of available geological and engineering data. In the absence of information on
fluid contacts, the lowest known structural occurrence of hydrocarbons controls the lower proved limit of
the reservoir.

| | (ii)    Reserves which can be produced economically through application of improved recovery techniques (such as fluid
injection) are included in the "proved" classification when 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.
| | -----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
| | (iii)    Estimates of proved reserves do not include the following:                                                                                                                                                                                                                                                                                                          

| | (A)    oil that may become available from known reservoirs but is classified separately as "indicated
additional reserves";                                                                       
| | --------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
| | (B)    crude oil, natural gas, and natural gas liquids, the recovery of which is subject to reasonable doubt
because of uncertainty as to geology, reservoir characteristics, or economic factors;
| | (C)    crude oil, natural gas, and natural gas liquids, that may occur in undrilled prospects; and                                                                                                
| | (D)    crude oil, natural gas, and natural gas liquids, that may be recovered from oil shales, coal, gilsonite
and other such sources.                                                            

Proved developed oil and gas reserves.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.Proved undeveloped reserves.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.
Under no circumstances should estimates for proved 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 tests in the area and in the same reservoir.

     Certain Staff Accounting Bulletins published subsequent to the promulgation of Regulation S-X have dealt with
matters relating to the application of financial accounting and disclosure rules for oil and gas producing activities.
In particular, the following interpretations extracted from Staff Accounting Bulletins set forth the Commission staff's
view on specific questions pertaining to proved oil and gas reserves.Economic producibility of estimated proved reserves can be supported to the satisfaction of the Office of
Engineering if geological and engineering data demonstrate with reasonable certainty that those reserves can be recovered
in future years under existing economic and operating conditions. The relative importance of the many pieces of
geological and engineering data which should be evaluated when classifying reserves cannot be identified in advance. In
certain instances, proved reserves may be assigned to reservoirs on the basis of a combination of electrical and other
type logs and core analyses which indicate the reservoirs are analogous to similar reservoirs in the same field which are
producing or have demonstrated the ability to produce on a formation test. (extracted from SAB-35)

     In determining whether "proved undeveloped reserves" encompass acreage on which fluid injection (or other
improved recovery technique) is contemplated, is it appropriate to distinguish between (i) fluid injection used for
pressure maintenance during the early life of a field and (ii) fluid injection used to effect secondary recovery when a
field is in the late stages of depletion?... The Office of Engineering believes that the distinction identified in the
above question may be appropriate in a few limited circumstances, such as in the case of certain fields in the North
Sea. The staff will review estimates of proved reserves attributable to fluid injection in the light of the strength of
the evidence presented by the registrant in support of a contention that enhanced recovery will be achieved. (extracted
from SAB-35)

     Companies should report reserves of natural gas liquids which are net to their leasehold interest, i.e., that
portion recovered in a processing plant and allocated to the leasehold interest. It may be appropriate in the case of
natural gas liquids not clearly attributable to leasehold interests ownership to follow instruction (b) of Item 2(b)(3)
of Regulation S-K and report such reserves separately and describe the nature of the ownership. (extracted from SAB-35)

     The staff believes that since coalbed methane gas can be recovered from coal in its natural and original
location, it should be included in proved reserves, provided that it complies in all other respects with the definition
of proved oil and gas reserves as specified in Rule 4-10(a)(2) including the requirement that methane production be
economical at current prices, costs, (net of the tax credit) and existing operating conditions. (extracted from SAB-85)

     Statements in Staff Accounting Bulletins are not rules or interpretations of the Commission nor are they
published as bearing the Commission's official approval; they represent interpretations and practices followed by the
Division of Corporation Finance and the Office of the Chief Accountant in administering the disclosure requirements of
the Federal securities laws.SUB-CATEGORIZATION OF DEVELOPED RESERVES (SPE/WPC DEFINITIONS)

     In accordance with guidelines adopted by the Society of Petroleum Engineers (SPE) and the World Petroleum
Congress (WPC), developed reserves may be sub-categorized as producing or non-producing.Producing.Reserves sub-categorized as producing are expected to be recovered from completion intervals which are open
and producing at the time of the estimate. Improved recovery reserves are considered producing only after the improved
recovery project is in operation.Non-Producing.Reserves sub-categorized as non-producing include shut-in and behind pipe reserves. Shut-in reserves are
expected to be recovered from (1) completion intervals which are open at the time of the estimate but which have not
started producing, (2) wells which were shut-in awaiting pipeline connections or as a result of a market
interruption, or (3) wells not capable of production for mechanical reasons. Behind pipe reserves are expected to be
recovered from zones in existing wells, which will require additional completion work or future recompletion prior to the
start of production.UNPROVED RESERVES (SPE/WPC DEFINITIONS)

     Unproved reserves are based on geologic and/or engineering data similar to that used in estimates of proved
reserves; but technical, contractual, economic, or regulatory uncertainties preclude such reserves being classified as
proved. Unproved reserves may be further classified as probable reserves and possible reserves.

     Unproved reserves may be estimated assuming future economic conditions different from those prevailing at the
time of the estimate. The effect of possible future improvements in economic conditions and technological developments
can be expressed by allocating appropriate quantities of reserves to the probable and possible classifications.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.

     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.Possible Reserves.Possible reserves are those unproved reserves which analysis of geological and engineering data
suggests are less likely to be recoverable than probable reserves. In this context, when probabilistic methods are used,
there should be at least a 10 percent probability that the quantities actually recovered will equal or exceed the sum of
estimated proved plus probable plus possible reserves.

     In general, possible reserves may include (1) reserves which, based on geological interpretations, could possibly
exist beyond areas classified as probable, (2) reserves in formations that appear to be petroleum bearing based on log
and core analysis but may not be productive at commercial rates, (3) incremental reserves attributed to infill drilling
that are subject to technical uncertainty, (4) reserves attributed to improved recovery methods when (a) a project or
pilot is planned but not in operation and (b) rock, fluid, and reservoir characteristics are such that a reasonable doubt
exists that the project will be commercial, and (5) reserves in an area of the formation that appears to be separated
from the proved area by faulting and geological interpretation indicates the subject area is structurally lower than the
proved area.

|100, 530 - 8TH AVENUE, S.W.600 17TH STREET, SUITE 1610N | CALGARY, ALBERTA T2P 3S8DENVER, COLORADO 80202-5416 | TEL (403) 262-2799(303) 623-9147 | FAX (403) 262-2790(303) 623-4258
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