FORM 6-K

                                  UNITED STATES
                       SECURITIES AND EXCHANGE COMMISSION

                             Washington, D.C. 20549


                            Report of Foreign Issuer
                                  July 23, 2004

                      Pursuant to Rule 13a-16 or 15d-16 of
                       the Securities Exchange Act of 1934


                                   OAO TATNEFT
                             (also known as TATNEFT)

                              (name of Registrant)

                                 75 Lenin Street
                          Almetyevsk, Tatarstan 423450
                               Russian Federation

                    (Address of principal executive offices)


         Indicate by check mark whether the registrant files or will file annual
reports under cover Form 20-F or Form 40-F.

                       Form 20-F...X.... Form 40-F........

         Indicate by check mark whether the registrant by furnishing the
information contained in this Form is also thereby furnishing the information to
the Commission pursuant to Rule 12g3-2(b) under the Securities Exchange Act of
1934.

                              Yes...... No...X....
<PAGE>
                                                                   July 23, 2004

On July 23, 2004 OAO Tatneft published on its web site at www.tatneft.ru the
following evaluation of its reserves as of January 1, 2004 prepared by Miller
and Lents, Ltd., independent international oil and gas consultants.




<PAGE>

                        [Miller & Lents, Ltd. Letterhead]






                                                    May 28, 2004

Mr. Shafagat F. Takhautdinov
General Director
Tatneft Joint Stock Company
75 Lenin Str.
Almetyevsk 423400
Republic of Tatarstan, Russia
                                  Re:    Evaluation of Reserves for Tatneft JSC
                                         Reserves and Net Revenues Forecast
                                         As of January 1, 2004
                                         Constant Price Case
Dear Mr. Takhautdinov:

         At your request, we estimated the net oil and gas reserves and future
net revenues as of January 1, 2004, for Tatneft JSC (Tatneft) in certain oil
fields of Tatarstan. The properties evaluated are located in the Volga-Ural Oil
Basin and include 63 developed and producing oil fields containing approximately
28,500 active completions and 7 undeveloped oil fields. Attachment 1 is a
location map of the Republic of Tatarstan that shows the producing areas.

         We performed our evaluations, which are designated as the Constant
Price Case, using the prices and expenses provided by Tatneft. The Constant
Price Case assumes no future escalations of oil or gas prices, operating
expenses, capital, or taxes above the respective January 1, 2004 values. The
aggregate results of our evaluations for Tatneft are as follows:
<TABLE>
<CAPTION>
=========================================== ========================================================================
                                                    Net Reserves                     Future Net Revenues
                                            ------------------------------ -----------------------------------------
                                               Crude and         Gas,       Undiscounted,        Discounted at
                                              Condensate,        Bcf             MM$             10% Per Year,
             Reserve Category                   MMBbls.                                              MM$
------------------------------------------- ---------------- ------------- ---------------- ------------------------
<S>                                             <C>                <C>          <C>                <C>
Proved Developed Producing                      3,515.3            890.8        27,639.0           10,946.1
------------------------------------------- ---------------- ------------- ---------------- ------------------------
Proved Developed Nonproducing                   2,067.1            523.8        13,562.3            2,927.1
------------------------------------------- ---------------- ------------- ---------------- ------------------------
Proved Undeveloped                                376.6             95.4         2,693.5              640.9
------------------------------------------- ---------------- ------------- ---------------- ------------------------
Additional Capital and Property Taxes                                           -3,055.5           -1,639.6
------------------------------------------- ---------------- ------------- ---------------- ------------------------
   Total Proved                                 5,959.0          1,510.0        40,839.3           12,874.5
------------------------------------------- ---------------- ------------- ---------------- ------------------------
Probable                                          941.0            238.4         7,444.6              803.8
------------------------------------------- ---------------- ------------- ---------------- ------------------------
Possible                                          160.8             40.8           727.3               31.3
=========================================== ================ ============= ================ ========================
</TABLE>

         Proved reserves may be further divided into volumes produced before and
after the expiration dates of their respective field production licenses. On
this basis, as of January 1, 2004, the estimated proved reserves and future net
revenues that are forecast until the time of current license expirations are as
follows:
<TABLE>
<CAPTION>

=========================================== ========================================================================
                                                     For the Time Period Until Current License Expirations
------------------------------------------- ------------------------------------------------------------------------
                                                    Net Reserves                     Future Net Revenues
------------------------------------------- ------------------------------ -----------------------------------------
                                               Crude and         Gas,       Undiscounted,        Discounted at
                                              Condensate,        Bcf             MM$             10% Per Year,
             Reserve Category                   MMBbls.                                              MM$
------------------------------------------- ---------------- ------------- ---------------- ------------------------
<S>                                             <C>               <C>           <C>                  <C>
Proved Developed Producing                      1,447.6           366.8         12,732.9             8,355.6
------------------------------------------- ---------------- ------------- ---------------- ------------------------
Proved Developed Nonproducing                     531.0           134.6          4,085.7             2,199.8
------------------------------------------- ---------------- ------------- ---------------- ------------------------
Proved Undeveloped                                137.0            34.7            965.1               442.0
------------------------------------------- ---------------- ------------- ---------------- ------------------------
Additional Capital and Property Taxes                                           -2,311.5            -1,418.4
------------------------------------------- ---------------- ------------- ---------------- ------------------------
   Total Proved                                 2,115.6           536.1         15,472.2             9,579.0
=========================================== ================ ============= ================ ========================
</TABLE>

         The estimated proved reserves and future net revenues forecast for the
time period following current license expiration dates, assuming renewal of the
licenses, are as follows:
<TABLE>
<CAPTION>

=========================================== ========================================================================
                                                   For the Time Period Following Current License Expirations
------------------------------------------- ------------------------------------------------------------------------
                                                    Net Reserves                     Future Net Revenues
------------------------------------------- ------------------------------ -----------------------------------------
                                               Crude and         Gas,       Undiscounted,        Discounted at
                                              Condensate,        Bcf             MM$             10% Per Year,
             Reserve Category                   MMBbls.                                              MM$
------------------------------------------- ---------------- ------------- ---------------- ------------------------
<S>                                             <C>               <C>          <C>                  <C>
Proved Developed Producing                      2,067.7           524.0        14,906.1             2,590.5
------------------------------------------- ---------------- ------------- ---------------- ------------------------
Proved Developed Nonproducing                   1,536.1           389.2         9,476.6               727.3
------------------------------------------- ---------------- ------------- ---------------- ------------------------
Proved Undeveloped                                239.6            60.7         1,728.4               198.9
------------------------------------------- ---------------- ------------- ---------------- ------------------------
Additional Capital and Property Taxes                                            -744.0              -221.2
------------------------------------------- ---------------- ------------- ---------------- ------------------------
   Total Proved                                 3,843.4           973.9        25,367.1             3,295.5
=========================================== ================ ============= ================ ========================
</TABLE>

         Proved, probable, and possible reserves were estimated in accordance
with standards of the Society of Petroleum Engineers, Inc. and World Petroleum
Congresses as defined on Attachment 2. The estimated net reserves are the same
as the gross reserves. The unified tax (previously a combination of royalty,
mineral replacement tax, and crude oil excise tax) was deducted from gross
revenues in determining net revenues but was not deducted from gross reserves in
determining net reserves. Reserves were projected for the economic life of the
field, without consideration of production or exploration license terms.

         Future net revenues as used herein are defined as the total gross
revenues less unified tax, operating costs, and capital expenditures. The total
gross revenues are the total revenues received by Tatneft after deduction of
transportation costs, export and customs duties, port expenses, excise tax,
value added tax, and special taxes. The oil and gas prices employed in the
computations of gross revenues were provided by Tatneft and are shown on
Attachments 3 and 4. Future net revenues do not include deductions for either
federal or local taxes on net profit.

         The operating expenses employed in estimating future net revenues are
the average operating expenses for the year 2003 that were provided by Tatneft.
We removed from the operating expenses the depreciation, well restoration costs,
and the unified tax. Restoration costs were included as capital for the portion
of the proved nonproducing reserves attributed to the restoration of shut-in
wells. The operating expenses for Tatneft are shown on Attachment 5.

         We allocated a portion of the operating expenses to the number of
active wells on a per-well basis and the remainder to the oil production rates
on a per-barrel basis, employing the allocations provided to us by Tatneft. We
assumed that the number of active wells for the large waterfloods would decline
to approximately one-half the fully developed well count estimated in last
year's evaluation as the fields declined in production and approached their
economic limit.

         Future capital costs for drilling and workover operations are based on
2003 costs provided by Tatneft and are shown on Attachment 6. The forecasts for
capital expenditures, other than drilling and completions, were based on data
provided by Tatneft through the year 2019 and are shown on Attachment 7.

         The proved developed producing reserves and production forecasts were
estimated by production decline extrapolations, water-oil ratio trends, or in a
few cases, by volumetric calculations. For some reservoirs with insufficient
performance history to establish trends, we estimated future production by
analogy with other reservoirs having similar characteristics. Production
declines were extrapolated to economic limits based on operating cost and oil
price data. The past performance trends of many reservoirs were influenced by
production curtailments, workovers, waterfloods, and/or infill drilling;
extrapolations of future performance are based, whenever possible, upon the
average performance trend of active wells during periods of stable field
activity.

         The estimated proved developed nonproducing reserves can be produced
from existing well bores but require capital costs for workovers, recompletions,
or restoration of shut-in wells. For wells shut in awaiting mechanical repair,
we assumed that the wells producing at rates greater than the economic limit at
the time of shut in will be returned to production at pre-shut-in levels and
will decline in production at the average reservoir decline rate. For wells
requiring recompletion, the estimates of reserves and producing rates are based
on volumetric calculations and analogies with other wells that commercially
produce from the same formation in the same field.

         The estimated proved undeveloped reserves require significant capital
expenditures, such as (1) costs for future development and infill wells and (2)
surface facilities. The proved undeveloped reserves are expected to be produced
from undeveloped portions of known reservoirs that have been adequately defined
by wells. Reserve estimates are based upon volumetric calculations that employ
recovery factors based on the performance of analogous reservoirs. Producing
rates are based upon analogy.

         The estimated probable and possible reserves are mainly undeveloped and
require significant capital expenditures. As new wells are drilled, portions of
these probable and possible reserve quantities will be either upgraded to a
higher reserve category or dropped entirely. The estimated probable reserves are
expected to be produced from undeveloped portions of known reservoirs not
adequately defined to be classified as proved. Two additional components of
probable reserves were included for currently producing reservoirs. For
reservoirs that are noncommercial or will become noncommercial while still
producing significant volumes of oil, it was assumed that these reservoirs could
be made commercial by shutting in high water-cut wells. These reserves are
considered probable rather than proved because of the uncertainty of results
from shutting in the high water-cut wells. Also, certain reservoirs under
waterflood may decline in production by a hyperbolic decline trend rather than a
linear exponential trend as was assumed for proved developed producing reserves.
For these reservoirs, we classified the incremental reserves as probable. The
estimated possible reserves are expected to be produced from undeveloped
portions of known reservoirs (1) where the reservoir is thin and uncertain to be
developed or (2) where subsurface control is limited. Estimates of reserves for
undeveloped portions of known reservoirs were estimated by volumetric methods.

         Reserve estimates from volumetric calculations and from analogies are
often less certain than reserve estimates based on well performance obtained
over a period during which a substantial portion of the reserves was produced.

         The probable and possible reserve volumes and the estimated future net
revenues therefrom have not been adjusted for uncertainty. None of the proved,
probable, or possible reserve volumes, nor the revenues projected therefrom,
should be combined with either of the other without adjustment for uncertainty.
Estimates of future net revenues and discounted future net revenues are not
intended and should not be interpreted to represent fair market values for the
estimated reserves. Future costs of abandoning facilities and wells and any
future costs of restoration of producing properties to satisfy environmental
standards were not deducted from total revenues as such estimates are beyond the
scope of this assignment.

         Estimated net gas reserves are based upon the past ratio of sales gas
to produced oil. Net gas reserves do not represent the total volumes of gas
expected to be produced with the net oil reserves.

         Structural maps, isopach maps of net oil sand, well status maps,
seismic data, cross sections, oil and water production data, well logs and core
information on key wells, and the Tatneft interpretation of key reservoir
parameters were provided by Tatneft. These were reviewed in detail and were
generally found to be acceptable interpretations. In certain cases, where
appropriate, original maps were prepared. The reservoir maps were employed to
estimate original oil in place and to classify the potentially productive areas
as either proved developed producing, proved developed nonproducing, proved
undeveloped, probable, or possible. Volumetric methods were employed to estimate
the original oil in place for each classified area.

         Attachment 8 shows a composite production forecast for Tatneft. This
figure shows the contribution of production from each proved reserve category.
Following the attachments are one-line summaries in both barrels and tonnes that
show reserves and cumulative future net revenues for each evaluated field.
Tatneft assigned fields to specific groups, which are also identified in the
one-line summaries.

         Following the one-line summaries are exhibits that are projections of
future production and net revenues for each reserve category and group.

         In conducting this evaluation, we relied upon (1) production histories,
(2) accounting and cost data, (3) ownership, (4) geological, geophysical, and
engineering data, and (5) drilling, recompletion, and workover schedules
supplied by Tatneft. These data were accepted as represented, as verification of
such data and information was beyond the scope of this assignment.

         The evaluations presented in this report, with the exceptions of those
parameters specified by others, reflect our informed judgments based on accepted
standards of professional investigation but are subject to those generally
recognized uncertainties associated with interpretation of geological,
geophysical, and engineering information. Government policies and market
conditions different from those employed in this study may cause the total
quantity of oil or gas to be recovered, actual production rates, prices
received, or operating and capital costs to vary from those presented in this
report.

                                                   Yours very truly,

                                                   MILLER AND LENTS, LTD.

                                                   By /s/ James C. Pearson
                                                     -------------------------
                                                        James C. Pearson
                                                        Chairman
JCP/hsd

<PAGE>

                                   LIST OF ATTACHMENTS
<TABLE>
<CAPTION>
                                                                             Attachment
                                                                                 No.
                                                                             ----------
<S>                                                                              <C>
Location Map ..............................................................      1
  Russian Federation, Tatarstan

Definitions for Oil and Gas Reserves
  Society of Petroleum Engineers, Inc. and Word Petroleum Congresses ......      2

Crude Oil and Gas Pricing, December 2002 ..................................      3

Natural Gas Prices, December 2002 .........................................      4

Operating Expenses, 2002 ..................................................      5

Average Capital Investment, 2002 ..........................................      6

Forecast of Other Capital Investments, Thousands US Dollars ...............      7

Total Oil Production Forecast
  Gross Yearly Oil Production (Barrels) ...................................      8a
  Gross Yearly Oil Production (Tonnes) ....................................      8b
</TABLE>

<PAGE>


                                                                    Attachment 1

Location Map

Russian Federation, Tatarstan

[Map of Central European Russia, with the Volga-Ural oil region borders
indicated by dotted line and Tatarstan appearing in the middle of that region
with its borders indicated by bold line.]


                                                                    Attachment 2
<PAGE>


Definitions

                      Definitions for Oil and Gas Reserves

       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 subclassified as
probable and possible reserves to denote progressively increasing uncertainty in
their recoverability.

       The intent of SPE and WPC in approving additional classifications beyond
proved reserves is to facilitate consistency among professionals using such
terms. In presenting these definitions, neither organization is recommending
public disclosure of reserves classified as unproved. Public disclosure of the
quantities classified as unproved reserves is left to the discretion of the
countries or companies involved.

       Estimation of reserves is done under conditions of uncertainty. The
method of estimation is called deterministic if a single best estimate of
reserves is made based on known geological, engineering, and economic data. The
method of estimation is called probabilistic when the known geological,
engineering, and economic data are used to generate a range of estimates and
their associated probabilities. Identifying reserves as proved, probable, and
possible has been the most frequent classification method and gives an
indication of the probability of recovery. Because of potential differences in
uncertainty, caution should be exercised when aggregating reserves of different
classifications.

       Reserves estimates will generally be revised as additional geologic or
engineering data becomes 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

       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.

       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.

Unproved Reserves

       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 reservoirs 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.

Reserve Status Categories

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

Developed. Developed reserves are expected to be recovered from existing wells
including reserves behind pipe. Improved recovery reserves are considered
developed only after the necessary equipment has been installed, or when the
costs to do so are relatively minor. Developed reserves may be subcategorized as
producing or nonproducing.

       Producing. Reserves subcategorized 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.

       Nonproducing. Reserves subcategorized as nonproducing 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 for market conditions or
pipeline connections, 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.

Undeveloped Reserves. Undeveloped reserves are expected to be recovered (1) from
new wells on undrilled acreage, (2) from deepening existing wells to a different
reservoir, or (3) where a relatively large expenditure is required to (a)
recomplete an existing well or (b) install production or transportation
facilities for primary or improved recovery projects.

Approved by the Board of Directors, Society of Petroleum Engineers (SPE), Inc.,
and the Executive Board, World Petroleum Congresses (WPC), March 1997.

<PAGE>
                                                                    Attachment 3

                           TATNEFT JOINT STOCK COMPANY
                            CRUDE OIL AND GAS PRICING
                                  DECEMBER 2003

--------------------------------------------------------------------------------
A. Domestic Price                                               Amounts
    Sales, tons                                                       4,689,128
    Contract Price                                             $         108.64
    Less: VAT and Special Taxes                                $         18.11
          Excise Tax                                           $           -
    General Deductions                                                   18.11
    Net Price for Tatneft                                      $         90.54
================================================================================
B. World Export Price
    Sales, tons                                                     10,668,158
    Contract Price                                             $        186.50
    Less: Transportation Cost                                  $         13.48
          Custom Fees                                                    -
          Excise Fee                                           $           -
          Export Duty                                          $         31.00
          Comercial Expenses                                   $          3.90
   General Deductions                                          $         48.38
Net Price for Tatneft                                          $        138.12
================================================================================
C. CIS Export Price
Sales, tons                                                          2,563,502
Contract Price, $                                                       169.99
Contract Price, RR                                                       5,007
Less: Transportation Cost                                                 6.52
          Custom Fees                                                    31.20
          VAT (20%)                                                      28.33
          Export Duty                                                    -
          Comercial Expenses                                              1.22
   - General Deductions                                                  67.27
Net Price for Tatneft, $                                       $        102.72
Net Price for Tatneft, RR                                                3,026
================================================================================
Weight Average Oil Price $/tone                                $        120.61
Weight Average Oil Price $/BBL                                 $        16.932
Net Gas Price, $ / MM3                                         $         83.00
Net Gas Price, $ / MCF                                         $         2.350
================================================================================
USD/Ruble Exchange Rate                                        $         29.45
Barrels of oil per tone                                                  7.123
================================================================================

<PAGE>

                                                                    Attachment 4

                               Natural Gas Prices
                               Tatneft Properties
                                 December, 2003
<TABLE>
<CAPTION>

A. Domestic Gas Price
<S>                                                   <C>                          <C>
                                                      RR/1000m(3)                    2,659.00
           Less: VAT                                  RR/1000m(3)                      443.17
         Net Domestic Gas Price                       RR/1000m(3)                    2,215.83
                                                     $US/1000m(3)                       75.23
                                                      $US/MCF                           2.130
----------------------------------------------------------------------------------------------
B. Export Gas Price
                                                      RR/1000m(3)                    5,575.00
           Less: Transportation                       RR/1000m(3)                      478.00
           Less: other commercial expenses            RR/1000m(3)                       37.00
         Net Domestic Gas Price                       RR/1000m(3)                    5,060.00
                                                     $US/1000m(3)                      171.79
                                                      $US/MCF                            4.86
           Percent Gas Exported (Yearly Average)                                         8.05
----------------------------------------------------------------------------------------------
C. Average Net Gas Price
                                                      RR/1000m(3)                    2,444.80
                                                     $US/1000m(3)                       83.00
                                                      $US/MCF                           2.350
----------------------------------------------------------------------------------------------
    D. Currency Exchange Rate                          RR/$US                           29.45

      Unit Conversion Factor                        Bbl/tonne                           7.123
----------------------------------------------------------------------------------------------
E. Sales Gas-Oil Ratio:
         Total Oil Produced                            Tonnes                      17,920,789
         Total Gas                                       1000m3                       916,409
         Gas Oil Ratio                                m3/tonne                           51.14
                                                       CF/bbl                             253
</TABLE>

<PAGE>
                                                                    Attachment 5

                           Tatneft Joint Stock Company
                             2003 Operating Expenses
<TABLE>
<CAPTION>

                              Cost Item                                             Total
<S>                                                                                    <C>
  1    Power to Recover Oil                                                            40,636
  2    Formation Pressure Maintenance                                                 157,052
  3    Field Workers' Main Salary                                                       9,219
  4    Field Workers' Additional Salary                                                 1,078
  5    Social Insurance                                                                 2,778
  6    Well Depreciation                                                               46,793
  7    Oil and Gas Collection and Transportation                                       48,185
  8    Oil Treatment                                                                   44,872
  9    Preparatory work                                                                     -
 10    Equipment Maintenance and Operation                                            276,938
 11    including Well Maintenance Services                                             65,461
 12    Shop Expenses                                                                   47,598
 13    General Production Expenses including:                                         320,772
 13a   Road Tax                                                                          330
 13b   Housing Deductions                                                                   -
 14    Production Taxes including:                                                    665,321
 14a   Royalty taxes (OAO Tatneft)                                                        212
                                                                                            -
       Subtotal                                                                           212
 14b                Production tax (OAO Tatneft)                                      665,109
                                                                                            -
                                                                 Subtotal             665,109
 15    Gross Production Costs                                                       1,661,241
 16    Depreciation of oil wells                                                       46,793
----------------------------------------------------------------------------------------------
 17    Estimate of Recompletions and Restorations                                      33,553
 18    Production Taxes                                                               665,321
 19    Total Deductions                                                               745,667
 20    NET OPERATING EXPENSE                                                          915,574
----------------------------------------------------------------------------------------------
       Production in thousand tonnes:                                                  25,640
       Exchange Rate: (RR per US$):                                                     29.45
       Average Monthly Operating Costs, US$:                                           76,298
       Active Well Completions:                                                        28,238
       Average Monthly Oil Production, MTonnes:                                         2,137
       Average Monthly Oil Production, MBarrels:                                       15,220

  0.65     of Operating Costs Based on Well Count
  0.35     of Operating Costs Based on Oil Production

                                                         Operating Cost:    $           1,756
                                                                        ----------------------
                                                                                 per well
                                                                                 per mo.
                                                                            $            1.75
                                                                        ----------------------
                                                                                   per
                                                                                  barrel
</TABLE>

<PAGE>



                                                                    Attachment 6


                           TATNEFT JOINT STOCK COMPANY
                         2003 AVERAGE CAPITAL INVESTMENT

Drill and Completion
Tatneft Properties
               Carboniferous                $        255,071    per well
               Devonian                     $        257,618    per well
-------------------------------------------------------------------------
 Recompletion
 Tatneft Properties                         $         22,003    per well
-------------------------------------------------------------------------
 Restoration of Shut-in Wells
 Tatneft Properties                         $         15,833    per well

<PAGE>



                                                                    Attachment 7

                           TATNEFT JOINT STOCK COMPANY

            Forecast of Other Capital Investments Thousand US Dollars

        (Does not include CAPEX for drilling and recompletion of wells a
                               nd well workovers)

--------------------------------------------------------------------------------
Data Source                 Year                               M $US
                            2004                            $           215,191
                            2005                            $           210,684
                            2006                            $           205,409
           ---------------------------------------------------------------------
                            2007                            $           199,425
                            2008                            $           192,802
                            2009                            $           185,631
                            2010                            $           177,971
                            2011                            $           169,915
           ---------------------------------------------------------------------
                            2012                            $           161,544
                            2013                            $           152,943
                            2014                            $           144,195
                            2015                            $           135,376
                            2016                            $           126,567
           ---------------------------------------------------------------------
                            2017                            $           117,385
                            2018                            $           109,246
                            2019                            $           101,283
           ---------------------------------------------------------------------
                     Total 2004 - 2019                      $         2,605,567
--------------------------------------------------------------------------------

<PAGE>
                                                                   Attachment 8a

[Graph of Tatneft total gross yearly oil production forecast in barrels, with
horizontal coordinates showing years from 1986 through 2023 and vertical
coordinates showing gross yearly oil production in barrels from 100,000 to
1,000,000. The graph is divided by dotted vertical line running through the year
2003 into actual (1986-2003) and forecast (2004-2023) production. The graph
shows actual production from proved producing reserves through the year 2003 and
forecast production from proved producing reserves plus proved non-producing
reserves plus proved undeveloped reserves through the year 2023. The graph
indicates that, notwithstanding decline in production from proved producing
reserves, gross yearly oil production is forecast to remain at approximately the
same levels through 2023 due to the development of proved non-producing and
proved undeveloped reserves.]



<PAGE>



                                                                   Attachment 8b

[Graph of Tatneft total gross yearly oil production forecast in tons, with
horizontal coordinates showing years from 1986 through 2023 and vertical
coordinates showing gross yearly oil production in tons from 100,00 to
1,000,000. The graph is divided by dotted vertical line running through the year
2003 into actual (1986-2003) and forecast (2004-2023) production. The graph
shows actual production from proved producing reserves through the year 2003 and
forecast production from proved producing reserves plus proved non-producing
reserves plus proved undeveloped reserves through the year 2023. The graph
indicates that, notwithstanding decline in production from proved producing
reserves, gross yearly oil production is forecast to remain at approximately the
same levels through 2023 due to the development of proved non-producing and
proved undeveloped reserves.]



<PAGE>


                                   SIGNATURES


     Pursuant to the requirements of the Securities Exchange Act of 1934, the
registrant has duly caused this report to be signed on its behalf by the
undersigned, thereunto duly authorized.


                                    OAO TATNEFT

                                    By:   /s/ Vladimir P. Lavushchenko
                                       --------------------------------
                                       Name:  Vladimir P. Lavushchenko
                                       Title: Deputy General Director
                                              for Economics, Chairman of
                                              Disclosure Committee

Date:  July 23, 2004