<PAGE>

                     U.S. Securities and Exchange Commission
                             Washington, D.C. 20549

                                   Form 10-KSB
(Mark One)

[X]              ANNUAL REPORT UNDER SECTION 13 OR 15(d) OF THE
                         SECURITIES EXCHANGE ACT OF 1934
                   For the fiscal year ended December 31, 2001



[ ]            TRANSITION REPORT UNDER SECTION 13 OR 15(d) OF THE
                SECURITIES EXCHANGE ACT OF 1934 [No Fee Required]


                For the transition period from _______ to _______

                        Commission file number 333-82389

                  Atlas-Energy for the Nineties-Public #8 Ltd.
                 (Name of small business issuer in its charter)

Pennsylvania                                                          25-1849286
(State or other jurisdiction of                                 (I.R.S. Employer
incorporation or organization)                               Identification No.)
311 Rouser Road
Moon Township, PA                                                          15108
(Address of principal executive offices)                              (Zip code)

Issuer's telephone number, including area code:  (412) 262-2830
Securities registered under Section 12(b) of the Exchange Act

       Title of each class            Name of each exchange on which registered
             None                                       None

Securities registered under Section 12(g) of the Exchange Act
                                      None
                                (Title of Class)

        Check whether the issuer (1) filed all reports required to be filed by
Section 13 or 15(d) of the Exchange Act during the past 12 months (or for such
shorter period that the registrant was required to file such reports), and (2)
has been subject to such filing requirements for the past 90 days. Yes X No
                                                                      ---  ---

        Check if there is no disclosure of delinquent filers in response to Item
405 of Regulation S-B contained in this form, and no disclosure will be
contained, to the best of registrant's knowledge, in definitive proxy or
information statements incorporated by reference in Part III of this Form 10-KSB
or any amendment to this Form 10-KSB. [X]

        State issuer's revenues for its most recent fiscal year. $2,517,000

        State the aggregate market value of the voting stock held by
non-affiliates of the Registrant. Not Applicable.

        Transitional Small Business Disclosure Format (check one):
        Yes     No X
            ---   ---


<PAGE>



                 ATLAS-ENERGY FOR THE NINETIES - PUBLIC #8 LTD.
                      (A Pennsylvania Limited Partnership)
                             INDEX TO ANNUAL REPORT
                                  ON FORM 10KSB
<TABLE>
<CAPTION>

PART I                                                                                                           Page
------                                                                                                        ---------
<S>                                                                                                            <C>
     Item 1:    Business.....................................................................................   3 - 5
     Item 2:    Properties...................................................................................   5 - 9
     Item 3:    Legal Proceedings............................................................................       9
     Item 4:    Submission of Matters to a Vote of Security Holders..........................................       9

PART II
-------

     Item 5:    Market for Registrant's Common Equity and Related Security Holder Matters....................      10
     Item 6:    Management's Discussion and Analysis of Financial Condition
                and Results of Operations.................................................................... 11 - 12
     Item 7:    Financial Statements and Supplementary Data.................................................. 13 - 24
     Item 8:    Changes in and Disagreements with Accountants
                on Accounting and Financial Disclosure.......................................................      25
     Item 9:    Directors, Executive Officers and Significant Employees,
                    Compliance with Section (16A) of the Exchange Act........................................ 25 - 27

PART III
--------

     Item 10:   Executive Compensation.......................................................................      28
     Item 11:   Security Ownership of Certain Beneficial Owners and Management...............................      28
     Item 12:   Certain Relationships and Related Transactions...............................................      29
     Item 13:   Exhibits and Reports on Form 8-K.............................................................      29

SIGNATURES...................................................................................................      30
----------
</TABLE>



                                       2
<PAGE>

                                     PART I

ITEM 1. DESCRIPTION OF BUSINESS

         Business Development. We were formed as a Pennsylvania limited
partnership on July 16, 1998, with Atlas Resources, Inc. (Atlas) as our managing
general partner, to drill natural gas development wells. We have no employees
and rely on our managing general partner for management. See Item 9 "Directors,
Executive Officers and Significant Employees, Compliance With Section 16(A) of
the Exchange Act."

         We began our drilling activities on our initial closing date of
December 1, 1998, and our final closing date was December 31, 1998. We received
total cash subscriptions from investors of $11,089,000 which were paid to our
managing general partner acting as operator and general drilling contractor
under the drilling and operating agreement. Our managing general partner
contributed cash and leases for a total capital contribution to us of
$3,148,200.

         We drilled and completed a total of 54.66 net development wells to the
Clinton/Medina geological formation in Pennsylvania and Ohio. These wells are
currently producing natural gas, which is our only product, and will continue to
do so until they are depleted at which time they will be plugged and abandoned.
We do not anticipate that we will sell any of our wells. No other wells will be
drilled and thus no additional funds will be required for drilling. See Item 2
"Properties" for information concerning our wells.

         Our ongoing operating and maintenance costs have been and are expected
to be fulfilled through revenues from our gas sales. Our managing general
partner receives a monthly well supervision fee of $275 for serving as operator
of each of our producing wells under the drilling and operating agreement. The
well supervision fee covers all normal and regularly recurring operating
expenses for the production, delivery and sale of gas, such as:

         o well tending, routine maintenance and adjustment;

         o reading meters, recording production, pumping, maintaining
           appropriate books and records; and

         o preparing reports to us and to government agencies.

         The well supervision fees, however, do not include costs and expenses
related to the purchase of equipment, materials or third party services and
brine disposal. If these expenses are incurred, we will pay at cost for third
party services and materials and a reasonable charge for services performed
directly by our managing general partner or its affiliates. Also, beginning
three years after each of our wells has been placed into production our managing
general partner, as operator, may retain $200 of our revenues per month to cover
the estimated future plugging and abandonment costs of the well. See Item 6
"Management's Discussion and Analysis or Plan of Operation."

         Markets and Regulations. Our managing general partner is responsible
for selling our natural gas production, and its policy is to treat all wells in
a given geographic area equally. Our natural gas is being sold as discussed in
Item 2, "Properties - Delivery Commitments."

                                       3
<PAGE>



       The Federal Energy Regulatory Commission ("FERC") regulates the
interstate transportation of natural gas and has sought to promote greater
competition in natural gas markets. For example, traditionally natural gas was
sold by producers to interstate pipeline companies which then resold the natural
gas to local distribution companies for resale to end-users. FERC changed this
market structure by requiring interstate pipeline companies to transport gas for
other natural gas suppliers or producers. FERC later issued Order 636 which
requires interstate pipeline companies to, among other things, separate their
natural gas sales services from their transportation services and provide an
open access transportation service that is comparable in quality for all gas
suppliers or producers. FERC Order 636 is designed to ensure that interstate
pipeline companies do not have a competitive advantage over other natural gas
sellers because they also provide transportation services. FERC has also enacted
other regulatory policies and competitive initiatives that are intended to
increase the flexibility of interstate natural gas transportation such as
requiring interstate pipeline companies to develop electronic bulletin boards to
provide standardized access to information concerning pipeline capacity and
prices and FERC Order 637 which removed price ceilings on short-term capacity
release transactions.

       The marketing of our natural gas production is also affected by numerous
other factors beyond our control and the effect of which we cannot accurately
predict. These factors include, but are not limited to, the following:

         o the availability and capacity of pipeline and other transportation
           facilities;

         o competition from other energy sources such as coal, oil and
           electricity;

         o local and state regulations regarding production and transportation;

         o fluctuating seasonal supply and demand because of various factors
           such as home heating requirements in the winter months;

         o political instability in oil producing countries; and

         o the amount of domestic production and foreign imports of natural gas
           and oil.

       In addition to FERC's regulation of the interstate transportation of
natural gas, the state regulatory agency where a producing natural gas well is
located provides a comprehensive statutory and regulatory scheme for oil and gas
operations such as ours including supervising the production activities and the
transportation of natural gas sold in intrastate markets. Our oil and gas
operations in Pennsylvania are regulated by the Department of Environmental
Resources, Division of Oil and Gas, and our oil and gas operations in Ohio are
regulated by the Ohio Department of Natural Resources, Division of Oil and Gas.
Among other things, the regulations involve:

         o new well permit and well registration requirements, procedures and
           fees;

         o minimum well spacing requirements;

         o restrictions on well locations and underground gas storage;

         o certain well site restoration, groundwater protection and safety
           measures;

         o landowner notification requirements;

         o certain bonding or other security measures;

         o various reporting requirements;

         o well plugging standards and procedures; and

         o broad enforcement powers.


                                       4
<PAGE>



         We believe we have complied in all material respects with applicable
state regulations and do not expect that these regulations will have a material
adverse impact on our operations. Our producing activities also must comply with
various federal, state and local laws covering the discharge of materials into
the environment, or otherwise relating to the protection of the environment.
Although this compliance may cause delays or increase our costs, we do not
believe these costs will be substantial. We cannot predict, however, the
ultimate costs of complying with present and future environmental laws and
regulations because these laws and regulations are constantly being revised and
we cannot obtain insurance to protect against many types of environmental
claims.

         There are also a number of proposals from time to time that are
considered in Congress and in the legislatures and agencies of various states
that if enacted would significantly and adversely affect the oil and gas
industry, including us. For example, a proposal limiting the disposal of
wastewater from our wells would substantially increase our operating costs.
However, we cannot predict what proposals, if any, will be enacted and their
subsequent effect on our activities.

         ITEM 2. PROPERTIES

         Drilling Activity. The following table shows information about the
wells we have drilled since our formation. We will not drill any more wells. All
the wells drilled were development wells, which means a well drilled within the
proved area of an oil or gas reservoir to the depth of a stratigraphic horizon
known to be productive. For the years ended December 31, 2001 and 2000,
respectively, we did not drill any wells.

         Summary of Productive Wells. The table below shows the number of our
productive gross and net wells by state at December 31, 2001 in which we have a
working interest. All of our wells are classified as gas wells.

                                            Number of Productive Wells
                                            --------------------------
         Location                            Gross                Net
                                         ------------         ----------
         Pennsylvania...................      57                54.16
         Ohio ..........................       1                  .50
                                           -----              -------
              Total.....................      58                54.66
                                           =====              =======

         Production. The following table shows the quantities of natural gas and
oil produced (net to our interest), average sales price, and average production
(lifting) costs per equivalent unit of production for the periods indicated.

<TABLE>
<CAPTION>
                                                                                                     Average Production
                                                                                                     Cost (Lifting Cost)
                                        Production                     Average Sales Price            per mcfe (1) (2)
                                -----------------------              -----------------------          ---------------
         Period Ending          Oil (bbls)    Gas (mcf)              per bbl         per mcf
         -------------          ----------    ---------              -------         -------
<S>                                               <C>                  <C>            <C>                   <C>
         2001............              -          511,200              $  -           $  4.92               $   .94
         2000............              -          697,800              $  -           $  3.85               $   .60
</TABLE>
----------------
(1) "Mcf" means one thousand cubic feet of natural gas. "Mcfe" means a thousand
    cubic feet equivalent. Oil production is converted to mcfe at the rate of
    six mcf per barrel ("bbl").
(2) Lifting costs include labor to operate the wells and related equipment,
    repairs and maintenance, materials and supplies, property taxes, insurance
    and gathering charges.

                                       5
<PAGE>



         Oil and Gas Reserves. The following tables summarize information
regarding our estimated proved natural gas and oil reserves as of December 31,
2001 and 2000. All of our reserves are located in the United States.

         The estimates relating to our proved natural gas and oil reserves and
future net revenues of natural gas and oil reserves are based on reports
prepared by the managing general partner and reviewed by Wright & Company, Inc.
In accordance with the prospectus and SEC guidelines, the standardized and SEC
PV-10 estimates of future net cash flows from proved reserves are made using
natural gas and oil sales prices in effect as of the dates of the estimates and
are held constant throughout the life of the properties other than when
different prices are fixed and determinable from applicable contracts. Our
estimates of proved reserves were based on the following weighted average
prices:

                                              Years Ended December 31
                                        -------------------------------------
                                             2001                 2000
                                        ----------------    -----------------

         Natural gas (per mcf).........    $ 3.99                 $ 4.42
         Oil (per bbl).................    $    -                 $    -

         Reserve estimates are imprecise and may be expected to change as
additional information becomes available from:

         o reservoir performance;

         o new geological and geophysical data; and

         o economic changes.

         Furthermore, estimates of natural gas and oil reserves, of necessity,
are projections based on engineering data, and there are uncertainties inherent
in the interpretation of this data as well as the projection of future rates of
production and the timing of development expenditures. Reservoir engineering is
a subjective process of estimating underground accumulations of natural gas and
oil that cannot be measured in an exact way, and the accuracy of any reserve
estimate is a function of the quality of available data and of engineering and
geological interpretation and judgment.

         Results of drilling, testing and production after the date of the
estimate may justify revision of this estimate. Future prices received from the
sale of natural gas and oil may be different from those used in preparing the
reports. The amounts and timing of future operating and development costs may
also differ from those used. Thus, we cannot assure you that the reserves set
forth in the following tables will ultimately be produced. You should not
construe the discounted future net cash inflows as representative of the fair
market value of our proved natural gas and oil properties. Discounted future net
cash inflows are based on projected cash inflows which do not provide for
changes in natural gas and oil prices other than when different prices are fixed
and determinable from applicable contracts or for escalation of expenses and
capital costs. The meaningfulness of these estimates is highly dependent on the
accuracy of the assumptions on which they were based.

         All natural gas reserves are evaluated at constant temperature and
pressure, which can affect the measurement of natural gas reserves. We deducted
operating costs, development costs and some production-related and ad valorem
taxes in arriving at the estimated future cash flows. We made no provision for
income taxes, and based the estimates on operating methods and existing
conditions prevailing at the dates indicated above. We cannot assure you that
these estimates are accurate predictions of future net cash flows from natural
gas and oil reserves or their present value.

                                       6
<PAGE>
<TABLE>
<CAPTION>




                                                                               Years Ended December 31
                                                                        --------------------------------------
                                                                              2001                 2000
                                                                        -----------------    -----------------
<S>                                                                     <C>                  <C>
         Natural gas reserves:
            Proved developed reserves (2)..........................          3,178,600            8,159,400
            Proved undeveloped reserves (3)........................                  -                    -
                                                                        -----------------    -----------------
              Total proved reserves of natural gas.................          3,178,600            8,159,400

         Oil reserves:
            Proved developed reserves (2)..........................                  -                    -
            Proved undeveloped reserves (3)........................                  -                    -
                                                                        -----------------    -----------------
              Total proved reserves of oil.........................                  -                    -
                                                                        -----------------    -----------------

                Total proved reserves (mcfe).......................          3,178,600            8,159,400
                                                                        =================    =================

         PV-10 estimate of cash flows of proved reserves
            (in thousands) (4):
            Proved developed reserves..............................      $   4,403,600        $  13,803,500
            Proved undeveloped reserves............................                  -                    -
                                                                        -----------------    -----------------
              Total PV-10 estimate.................................      $   4,403,600        $  13,803,500
                                                                        =================    =================
</TABLE>


-------------------
(1) "Proved reserves" generally means 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 by contractual
    arrangements, but not escalations based on future conditions. Reservoirs are
    considered proved if economic production is supported by either actual
    production or conclusive formation test. The area of a reservoir considered
    proved includes: that portion delineated by drilling and defined by gas-oil
    and/or oil-water contacts, if any; and 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.

(2) "Proved developed oil and gas reserves" generally means reserves that can be
    expected to be recovered through existing wells with existing equipment and
    operating methods.

(3) "Proved undeveloped reserves" generally means reserves that are expected to
    be recovered either from new wells on undrilled acreage or from existing
    wells where a relatively major expenditure is required for recompletion.
    Reserves on undrilled acreage are limited to those drilling units offsetting
    productive units that are reasonably certain of production when drilled.

(4) The present value of estimated future net cash flows is calculated by
    discounting estimated future net cash flows by 10% annually.

         Since December 31, 2001, we do not believe there has been a favorable
or adverse event which would cause a significant change in our estimated
reserves. We have not filed any estimates (on a consolidated basis) of our oil
and gas reserves with, nor were such estimates included in any reports to, any
Federal or foreign governmental agency other than the SEC within the 12 months
before the date of this filing. For additional information concerning oil and
gas reserves and activities, see the notes to our Financial Statements.

         Title to Properties. Our interests in producing acreage are in the form
of assigned interests in leases. Such properties are subject to customary
royalty interests generally contracted for in connection with the acquisition of
properties and could be subject to liens incident to operating agreements, liens
for current taxes and other burdens. We believe that none of these burdens
materially interfere with the use of such properties in the operation of our
business.


                                       7
<PAGE>



         Acreage. The table below shows the acres of developed and undeveloped
oil and gas acreage in which we have an interest by state at December 31, 2001.
<TABLE>
<CAPTION>

                                                         Developed Acreage                Undeveloped Acreage (3)
                                                         -----------------                -----------------------
Location                                           Gross (1)           Net (2)            Gross            Net
--------                                           ---------           -------            ------           ---
<S>                                                   <C>                <C>             <C>           <C>
  Pennsylvania................................        2,675              2,644                  -               -
  Ohio........................................           40                 20                  -               -
                                                 ----------         ----------          ---------       ---------
     Total....................................        2,715              2,664                  -               -
                                                 ==========         ==========          =========       =========
</TABLE>

----------------
(1) A "gross" acre is an acre in which we own a working interest.

(2) A "net" acre equals the actual working interest we own in one gross acre
    divided by one hundred. For example, a 50% working interest in an acre is
    one gross acre, but a .50 net acre.

(3) "Undeveloped acreage" is those lease acres on which wells have not been
    drilled or completed to a point that would permit the production of
    commercial quantities of oil and gas regardless of whether or not the
    acreage contains proved reserves.

       Delivery Commitments. All of our gas in the Warren County area of
Pennsylvania, which represents approximately 25% of our total production, was
and is being sold to Belden & Blake Corporation pursuant to a joint venture
agreement with Belden & Blake. Our managing general partner, Resource Energy,
Inc. and Atlas Energy Group, Inc. have a gas supply agreement with First Energy
Solutions Corporation for a 10-year term which began on April 1, 1999. First
Energy Solutions Corporation is the marketing affiliate of First Energy
Corporation, a large regional electric utility listed on the New York Stock
Exchange. Subject to certain exceptions, First Energy Solutions Corporation must
buy all of the natural gas produced and delivered by our managing general
partner and its affiliates, which includes us, at certain specific delivery
points with the facilities of: East Ohio Gas Company, National Fuel Gas
Distribution, and Peoples Natural Gas Company, which are local distribution
companies, and National Fuel Gas Supply, Columbia Gas Transmission Corporation,
Tennessee Gas Pipeline Company, and Texas Eastern Transmission Company, which
are interstate pipelines. Generally, all of our gas was and is being sold under
the agreement with First Energy Solutions Corporation other than the gas being
sold under our managing general partner's contract with Wheatland Tube which
expired September, 2001 and the agreement with Belden & Blake. We are not
required to provide any fixed and determinable quantities of gas under any
agreement other than agreements that are a consequence of limited hedging
agreements with First Energy Solutions Corporation, as discussed below.

       The First Energy Solutions Corporation agreement establishes an indexed
price formula for each delivery point during an initial period and requires the
parties to negotiate new pricing arrangements at each delivery point for
subsequent periods. If, at the end of any applicable period, our managing
general partner and First Energy Solutions Corporation cannot agree to a new
price for any delivery point, then our managing general partner may solicit
offers from third-parties, but First Energy Solutions Corporation retains the
right to match any offer which is received. If First Energy Solutions
Corporation does not match a particular offer, then the natural gas associated
with that offer may be sold to the third-party. For example, during the period
April 1, 2000 through March 31, 2001, our managing general partner and its
affiliates sold natural gas delivered to National Fuel Gas Supply to entities
other than First Energy Solutions Corporation pursuant to this process. This
process is repeated at the end of each contract period.

              Our managing general partner and First Energy Solutions
Corporation have generally been able to agree to new pricing arrangements for
all the delivery points under the agreement. Thus, for the next twelve months,
our managing general partner anticipates that approximately 25% of our natural
gas will be sold to Belden & Blake and the remainder will be sold to First
Energy Solutions Corporation.

                                       8
<PAGE>



         The marketing of natural gas has been influenced by the availability of
financial instruments that may be used to hedge the price that will ultimately
be paid for future deliveries of natural gas. Our managing general partner
purchases and sells natural gas futures and options contracts to limit our
exposure to pricing change. These contracts may include regulated NYMEX futures
and options contracts and non-regulated over-the-counter contracts with
qualified counter-parties and generally cover periods from one month to up to
two years in the future. To assure that the financial instruments will be used
solely for hedging price risk and not for speculative purposes, our managing
general partner has established a committee to assure that all financial trading
is done in compliance with hedging policies and procedures. Our managing general
partner has not and does not intend to contract for positions that it cannot
offset with actual production. Although hedging provides our managing general
partner's partnerships, including us, some protection against falling prices,
these activities could also reduce the potential benefit from price increases,
depending on the instrument. The portion of our natural gas that is hedged
changes from time to time.

         As a full service marketer, First Energy Solutions Corporation also
utilizes NYMEX based financial instruments to hedge their pricing exposure and
from time to time makes price hedging opportunities available to our managing
general partner. These transactions are similar to NYMEX based futures
contracts, swaps and options, but also require firm delivery of the hedged
quantity. Thus, our managing general partner limits these arrangements to much
smaller quantities than those projected to be available at any delivery point.
The price paid by First Energy Solutions Corporation for certain volumes of
natural gas sold pursuant to these hedge agreements, may be significantly
different than the underlying monthly spot market value.


ITEM 3. LEGAL PROCEEDINGS
        None.


ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITIES HOLDERS
        None.



                                       9

<PAGE>


                                     PART II

ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED SECURITY HOLDER
        MATTERS

         Market Information. There is no established public trading market for
our units and we do not anticipate a market will develop. Our units may be
transferred only in accordance with the provisions of Article VI of our
partnership agreement which require that:

         o our managing general partner consent;

         o the transfer not result in materially adverse tax consequences to us;
           and

         o the transfer not violate federal or state securities laws.

An assignee of a unit may become a substituted partner only on meeting the
following conditions:

         o the assignor gives the assignee the right;

         o our managing general partner consents to the substitution;

         o the assignee pays to us all costs and expenses incurred in connection
           with the substitution; and

         o the assignee executes and delivers the instruments which our managing
           general partner requires to effect the substitution and to confirm
           his or her agreement to be bound by the terms of our partnership
           agreement.

         A substitute partner is entitled to all of the rights of full ownership
of the assigned units, including the right to vote.

         Holders. As of December 31, 2001, we had 380 interest holders.

         Distributions. Our managing general partner reviews our accounts
quarterly to determine whether cash distributions are appropriate and the amount
to be distributed, if any. We distribute those funds to our partners and the
other participants which our managing general partner determines are not
necessary for us to retain. We will not advance or borrow for purposes of
distributions if the amount of the distributions would exceed our accrued and
received revenues for the previous four quarters, less paid and accrued
operating costs with respect to the revenues.

        The determination of the revenues and costs will be made in accordance
with generally accepted accounting principles, consistently applied, and cash
distributions to our managing general partner may only be made in conjunction
with distributions to you and the other participants.

         During the calendar year ending December 31, 2001, we distributed the
following:

         o $1,763,500 to our limited partners; and

         o $828,500 to our managing general partner.

                                       10
<PAGE>



ITEM 6. MANAGEMENT'S DISCUSSION AND ANALYSIS OR PLAN OF OPERATION

Forward-Looking Statements

         When used in this Form 10-K, the words "believes" "anticipates"
"expects" and similar expressions are intended to identify forward-looking
statements. Such statements are subject to certain risks and uncertainties more
particularly described in Item 1 of this report. These risks and uncertainties
could cause actual results to differ materially. Readers are cautioned not to
place undue reliance on these forward-looking statements, which speak only as of
the date hereof. We undertake no obligation to publicly release the results of
any revisions to forward-looking statements which we may make to reflect events
or circumstances after the date of this Form 10-K or to reflect the occurrence
of unanticipated events.

         Management's Discussion and Analysis should be read in conjunction with
our Financial Statements and the notes to our Financial Statements.

Results of Operations

         The following table set forth information relating to revenues
recognized and costs and expenses incurred, daily production volumes, average
sales prices and production cost per equivalent unit during the periods
indicated:
<TABLE>
<CAPTION>


                                                                                                   Years Ended
                                                                                        -----------------------------
                                                                                                  December 31,
                                                                                        -----------------------------
                                                                                            2001              2000
                                                                                        -----------       -----------
<S>                                                                                       <C>             <C>
Revenues (in thousands):
   Gas(1)...............................................................................  $   2,517       $     2,689
   Oil..................................................................................  $       -       $         -
Production volumes:
   Gas (thousands of cubic feet (mcf)/day)..............................................      1,401             1,912
   Oil (barrels (bbls)/day).............................................................          -                 -
Average sales price:
   Gas (per mcf)........................................................................  $    4.92       $      3.85
   Oil (per bbl)........................................................................  $       -       $         -
Production costs:
   As a percent of sales................................................................         19%               16%
   Per equivalent mcf...................................................................  $     .93       $       .60
</TABLE>

----------
(1) Excludes sales of residual gas and sales to landowners.

         Revenues. During the year ended December 31, 2001, we had a net loss of
$2,520,600 as compared with net earnings for the year ended December 31, 2000 of
$1,248,600.

         Our natural gas revenues were $2,517,000 in the year ended December 31,
2001, a decrease of $171,500 (6%) from $2,688,500 in the year ended December 31,
2000 due to a 27% ($918,700) decrease in production volumes partially offset by
a 28 % increase ($747,200) in the average sales price of natural gas.

         The decrease in gas production volumes results primarily from the
normal decline inherent in the life of a well. The impact of the lower gas
production more than offset the increase in natural gas prices, which increased
by $1.07 per Mcf to $4.92 per Mcf in 2001. Our revenues from our natural gas
sales will be affected by changes in natural gas prices which are driven by
market conditions as discussed in Item 1 "Description of Business Atlas-Energy
for the Nineties-Public #8 Ltd. (the "Partnership") - Markets and Regulation."

                                       11
<PAGE>



         Expenses. Production expenses for the year ended December 31, 2001
amounted to $480,100 compared to $419,800 for the year ended December 31, 2000,
an increase of $60,300 (14%). The increase is attributable to a significant
increase in third party charges associated with wells not operated by the
managing general partner partially offset by decreased transportation expense
due to lower production volumes being transported.

         Depletion and depreciation of oil and gas properties as a percentage of
oil and gas revenues was 62% in the year ended December 31, 2001 compared to 37%
in the year ended December 31, 2000. This percentage change is directly
attributable to changes in our oil and gas reserve quantities, product prices
and fluctuations in the depletable cost basis of oil and gas properties.

         Impairment of oil and gas properties for year ended December 31, 2001
was $2,937,700. Annually, we compare the carrying value of our proved developed
oil and gas producing properties to the estimated future net cash flows from
such properties in order to determine whether their carrying values exceeds the
estimated future cash flows. As a result of this assessment, an impairment
change was recognized for the year ending December 31, 2001.

         General and Administrative expenses for the year ended December 31,
2001 amounted to $81,700 compared to $54,000 for the year ended December 31,
2000, an increase of $27,800 (52%). The increase is attributable to the fact
that not all the wells were producing at the year ending December 2000. The
remaining partnership wells were completed during the year ending December 2001
increasing the overall administrative charge for the year.

         Liquidity and Capital Resources. Cash provided by operating activities
increased $1,130,000 primarily due an increase of $1.07 per mcf in the average
price received for our gas production sold during the twelve months ending
December 2001, as compared to the same period ending December 31, 2000.
Offsetting this increase was a $1,149,900 increase in distributions to partners
for the same periods.

         There were no new material commitments for us to make capital
expenditures during the period and we do not expect any in the foreseeable
future. Any additional funds, if required will be obtained from production
revenues or borrowings from our managing general partner or its affiliates,
which are not contractually committed to make a loan. The amount that may be
borrowed may not at any time exceed 5% of our total subscriptions, and no
borrowings will be obtained from third parties.

         Recent Accounting Pronouncements. The Financial Accounting Standards
Board issued Statement of Financial Accounting Standards No. 133 and No. 138,
ACCOUNTING FOR DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES. SFAS No. 133/138
establishes accounting and reporting standards for derivative instruments,
including certain derivative instruments embedded in other contracts, and for
hedging activities. It requires entities to recognize all derivatives as either
assets or liabilities in the statement of financial position and measure those
instruments at fair value. The adoption of these new accounting standards did
not have a material impact on the Partnership's financial statements.

         In July 2001, the Financial Accounting Standards Board issued SFAS No.
143, "Accounting for Asset Retirement Obligations". SFAS No. 143 requires
entities to record the fair value of a liability for an asset retirement
obligation in the period in which it is incurred and a corresponding increase in
the carrying amount of the related long-lived asset and will be effective for
fiscal years beginning after July 15, 2002. The Partnership is required to adopt
SFAS No. 143 effective January 1, 2003 and has not yet determined the impact of
this new accounting standard.


                                       12
<PAGE>


ITEM 7. FINANCIAL STATEMENTS

               REPORT OF INDEPENDENT CERTIFIED PUBLIC ACCOUNTANTS
               --------------------------------------------------

To the Partners
---------------
Atlas-Energy for The Nineties - Public #8 Ltd.
A Pennsylvania Limited Partnership


We have audited the accompanying balance sheets of Atlas-Energy for The Nineties
- Public #8 Ltd., A Pennsylvania Limited Partnership, as of December 31, 2001
and 2000, and the related statements of operations, changes in partners' capital
accounts and cash flows for each of the years then ended. These financial
statements are the responsibility of the Partnership's management. Our
responsibility is to express an opinion on these financial statements based on
our audits.

We conducted our audits in accordance with auditing standards generally accepted
in the United States of America. Those standards require that we plan and
perform the audit to obtain reasonable assurance about whether the financial
statements are free of material misstatement. An audit includes examining, on a
test basis, evidence supporting the amounts and disclosures in the financial
statements. An audit also includes assessing the accounting principles used and
significant estimates made by management, as well as evaluating the overall
financial statement presentation. We believe that our audits provide a
reasonable basis for our opinion.

In our opinion, the financial statements referred to above present fairly, in
all material respects, the financial position of Atlas-Energy for The Nineties -
Public #8 Ltd. as of December 31, 2001 and 2000 and the results of its
operations, and cash flows for each of the years then ended, in conformity with
accounting principles generally accepted in the United States of America.

As described in Note 9 to the financial statements, as of January 1, 2001, the
Partnership changed its method of accounting for derivative instruments and
hedging activities.




/s/ Grant Thornton L.L.P.
-------------------------
Cleveland, Ohio
February 18, 2002


                                       13

<PAGE>




                 ATLAS-ENERGY FOR THE NINETIES - PUBLIC #8 LTD.
                      (A Pennsylvania Limited Partnership)

                                 BALANCE SHEETS
<TABLE>
<CAPTION>


                                                                                                  December 31,
                                                                                        -----------------------------
                                                                                            2001              2000
                                                                                       --------------    --------------
<S>                                                                                    <C>               <C>
ASSETS
Cash.............................................................................      $       19,700    $       19,800
Accounts receivable - affiliate..................................................             334,900           773,200
Unrealized hedging gains.........................................................              17,900                 -

Oil and gas wells and properties (successful efforts)............................          12,573,800        12,573,800
Less accumulated depletion and depreciation......................................          (5,477,500)         (990,600)
                                                                                       --------------    --------------
                                                                                            7,096,300        11,583,200
                                                                                       --------------    --------------
                                                                                       $    7,468,800    $   12,376,200
                                                                                       ==============    ==============


LIABILITIES AND PARTNERS' CAPITAL
Accounts payable - affiliate.....................................................      $      198,300                 -
Accrued liabilities..............................................................                   -            11,000

Partners' capital:
   Managing General Partner......................................................             872,000         1,583,900
   Limited Partners (1,111 units)................................................           6,380,600        10,781,300
   Accumulated other comprehensive income........................................              17,900                 -
                                                                                       --------------    --------------
                                                                                            7,270,500        12,365,200
                                                                                       --------------    --------------
                                                                                       $    7,468,800    $   12,376,200
                                                                                       ==============    ==============
</TABLE>

    The accompanying notes are an integral part of these financial statements

                                       14


<PAGE>




                 ATLAS-ENERGY FOR THE NINETIES - PUBLIC #8 LTD.
                      (A Pennsylvania Limited Partnership)

                            STATEMENTS OF OPERATIONS
<TABLE>
<CAPTION>


                                                                                                   Years Ended
                                                                                        -----------------------------
                                                                                                  December 31,
                                                                                        -----------------------------
                                                                                            2001              2000
                                                                                       --------------    -------------
<S>                                                                                    <C>               <C>
REVENUES
Natural gas and oil..............................................................      $    2,517,000    $   2,688,500
Interest income..................................................................              11,000           24,400
                                                                                       --------------    -------------
                                                                                            2,528,000        2,712,900
                                                                                       --------------    -------------
COSTS AND EXPENSES
Production expenses..............................................................             480,100          419,800
Depletion and depreciation of oil and gas properties.............................           1,549,100          990,600
Impairment of oil and gas properties.............................................           2,937,700                -
General and administrative expenses..............................................              81,700           53,900
                                                                                       --------------    -------------
                                                                                            5,048,600        1,464,300
                                                                                       --------------    -------------

Net (loss) earnings..............................................................      $   (2,520,600)   $   1,248,600
                                                                                       ==============    =============

Allocation of net earnings:

   Managing General Partner......................................................      $      116,700    $     455,500
                                                                                       ==============    =============

   Limited Partners..............................................................      $   (2,637,300)   $     793,100
                                                                                       ===============   =============

      Net earnings per limited partnership interest..............................      $       (2,374)   $         714
                                                                                       ===============   =============

</TABLE>

    The accompanying notes are an integral part of these financial statements

                                       15



<PAGE>




                 ATLAS-ENERGY FOR THE NINETIES - PUBLIC #8 LTD.
                      (A Pennsylvania Limited Partnership)

               STATEMENTS OF CHANGES IN PARTNERS' CAPITAL ACCOUNTS
                     YEARS ENDED DECEMBER 31, 2001 AND 2000
<TABLE>
<CAPTION>



                                                                                             Accumulated
                                                               Managing                         Other
                                                                General         Limited     Comprehensive
                                                                Partner        Partners        Income            Total
                                                             -------------   ------------- --------------- -------------
<S>                                                         <C>              <C>             <C>           <C>
Balance at January 1, 2000................................. $    1,469,800   $  11,088,900   $         -   $  12,558,700

   Participation in revenue and expenses:
    Net production revenues................................        657,900       1,610,800             -       2,268,700
    Subordination of Managing General
     Partners' income......................................        (76,800)         76,800             -               -
    Interest income........................................          7,100          17,300             -          24,400
    Depletion and depreciation.............................       (117,100)       (873,500)            -        (990,600)
    General and administrative.............................        (15,600)        (38,300)            -         (53,900)
                                                            --------------   -------------   -----------   -------------
        Net earnings and comprehensive income..............        455,500         793,100             -       1,248,600
    Distributions to partners..............................       (341,400)     (1,100,700)            -      (1,442,100)
                                                            --------------   -------------   -----------   -------------

Balance at December 31, 2000............................... $    1,583,900   $  10,781,300   $         -   $  12,365,200

Comprehensive income (loss):
   Participation in revenue and expenses:
     Net production revenues...............................        590,700       1,446,200             -       2,036,900
     Subordination reimbursement...........................         76,800         (76,800)            -               -
     Interest income.......................................          3,200           7,800             -          11,000
     Depletion and depreciation............................       (183,100)     (1,366,000)            -      (1,549,100)
     Impairment of lease costs.............................       (347,300)     (2,590,400)                   (2,937,700)
     General and administrative............................        (23,700)        (58,000)            -         (81,700)
                                                            --------------   -------------   -----------   -------------
        Net earnings (loss)................................        116,600      (2,637,200)            -      (2,520,600)
     Cumulative effect of accounting change................              -               -      (122,000)       (122,000)
     Derivative losses reclassed into gas sales............              -               -       (76,300)        (76,300)
     Change in fair value of cash flow hedges..............              -               -       216,200         216,200
                                                                                                           -------------
        Comprehensive income (loss)........................                                                   (2,502,700)
     Distributions to partners.............................       (828,500)     (1,763,500)            -      (2,592,000)
                                                            --------------   -------------   -----------   -------------
Balance at December 31, 2001............................... $      872,000   $   6,380,600   $    17,900   $   7,270,500
                                                            ==============   =============   ===========   =============

</TABLE>

    The accompanying notes are an integral part of these financial statements

                                       16


<PAGE>



                 ATLAS-ENERGY FOR THE NINETIES - PUBLIC #8 LTD.
                      (A Pennsylvania Limited Partnership)

                            STATEMENTS OF CASH FLOWS
<TABLE>
<CAPTION>



                                                                                                   Years Ended
                                                                                        -----------------------------
                                                                                                  December 31,
                                                                                        -----------------------------
                                                                                            2001              2000
                                                                                       --------------    -------------
<S>                                                                                    <C>               <C>
Cash flows from operating activities:
Net earnings.........................................................................  $   (2,520,600)   $   1,248,600
Adjustments to reconcile net earnings to net cash provided by operating activities:
   Impairment of oil and gas leases .................................................       2,937,700                -
   Depletion and depreciation:.......................................................       1,549,100          990,600
   Decrease (increase) in accounts receivable........................................         438,300         (785,000)
   Increase in accounts payable and accrued liabilities..............................         187,400           77,000
                                                                                       --------------    -------------

Net cash provided by operating activities............................................       2,591,900        1,461,900


Cash flows from financing activities:
Distributions to partners............................................................      (2,592,000)      (1,442,100)
                                                                                       --------------    -------------

Net cash used in financing activities................................................      (2,592,000)      (1,442,100)
                                                                                       --------------    -------------
Net (decrease) increase in cash......................................................            (100)          19,800
                                                                                       ---------------   -------------

Cash at beginning of year............................................................          19,800                -
                                                                                       --------------    -------------

Cash at end of year..................................................................  $       19,700    $      19,800
                                                                                       ==============    =============


</TABLE>

    The accompanying notes are an integral part of these financial statements

                                       17


<PAGE>


                 ATLAS-ENERGY FOR THE NINETIES - PUBLIC #8 LTD.
                      (A Pennsylvania Limited Partnership)

                          NOTES TO FINANCIAL STATEMENTS
                           December 31, 2001 and 2000


NOTE 1 - NATURE OF OPERATIONS

         Atlas-Energy for the Nineties - Public #8 Ltd. (the "Partnership") is a
Pennsylvania Limited Partnership which includes Atlas Resources, Inc. ("Atlas")
of Pittsburgh, Pennsylvania, as Managing General Partner and Operator, and 380
Limited Partners. The Partnership was formed on June 18, 1999 to drill and
operate gas wells located primarily in Mercer County, Pennsylvania. At December
31, 2001, the Partnership had various working interests in 58 wells.

NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

         A summary of significant accounting policies consistently applied in
the preparation of the accompanying financial statements follows:

         Basis of Accounting
         -------------------

         The financial statements are prepared in accordance with accounting
principles generally accepted in the United States of America.

         Oil and Gas Wells and Properties
         --------------------------------

         The Partnership uses the successful efforts method of accounting for
oil and gas producing activities. Costs to acquire mineral interests in oil and
gas properties and to drill and equip wells are capitalized. Depreciation and
depletion is computed on a field-by-field basis by the unit-of-production method
based on periodic estimates of oil and gas reserves.

         Undeveloped leaseholds and proved properties are assessed periodically
to determine whether there has been a decline in value and, if such decline is
indicated, a loss is recognized. The Partnership compares the carrying value of
its proved developed oil and gas producing properties to the estimated future
net cash flows from such properties in order to determine whether their carrying
values should be reduced. As a result of this assessment, an impairment loss of
2,937,700 was recognized in 2001.

        On an ongoing basis, the Partnership estimates the costs of future
dismantlement, restoration, reclamation, and abandonment of its gas and oil
producing properties. Additionally, the Partnership estimates the salvage value
of equipment recoverable upon abandonment. At December 31, 2001 and 2000, the
Partnership estimated that equipment salvage values would be sufficient to
recover the estimated costs of future dismantlement, restoration, reclamation,
and abandonment.



                                       18
<PAGE>


                 ATLAS-ENERGY FOR THE NINETIES - PUBLIC #8 LTD.
                      (A Pennsylvania Limited Partnership)

                   NOTES TO FINANCIAL STATEMENTS - (Continued)
                           December 31, 2001 and 2000

NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

         Significant Estimates
         ---------------------

         Certain amounts included in or affecting the Partnership's financial
statements and related disclosures must be estimated, requiring the Partnership
to make certain assumptions with respect to values or conditions that cannot be
known with certainty at the time the financial statements are prepared.

         The preparation of financial statements in conformity with generally
accepted accounting principles requires the Partnership to make estimates and
assumptions that affect:

         o the amount the Partnership reports for assets and liabilities;

         o the Partnership gas and oil reserves

         o the amounts the Partnership reports for revenues and expenses during
           the reporting period.

         Therefore, the reported amounts of the Partnership's assets and
liabilities, revenues and expenses and associated disclosures with respect to
gas and oil reserves are necessarily affected by these estimates. The
Partnership evaluates these estimates on an ongoing basis, utilizing historical
experience, consultation with experts and other methods the Partnership
considers reasonable in the particular circumstances. Nevertheless, actual
results may differ significantly from the Partnership's estimates. Any effects
on the Partnership's business, financial position or results of operations
resulting from revisions to these estimates are recorded in the period in which
the facts that give rise to the revision become known.

         Revenue Recognition
         -------------------

         Revenues from the sale of natural gas and oil are recognized when the
gas and oil are delivered to the purchaser.

         New Accounting Standard
         -----------------------

         In July 2001, the Financial Accounting Standards Board issued SFAS No.
143, "Accounting for Asset Retirement Obligations". SFAS No. 143 requires
entities to record the fair value of a liability for an asset retirement
obligation in the period in which it is incurred and a corresponding increase in
the carrying amount of the related long-lived asset and will be effective for
fiscal years beginning after July 15, 2002. The Partnership is required to adopt
SFAS No. 143 effective January 1, 2003 and has not yet determined the impact of
this new accounting standard.

         Major Customer
         --------------

         Substantially all of the Partnership's revenues were derived from one
customer. However, the market for gas and oil production is a diverse open
market and other purchasers are readily available.

NOTE 3 - FEDERAL INCOME TAXES

         The Partnership is not treated as a taxable entity for federal income
tax purposes. Any item of income, gain, loss, deduction or credit flows through
to the partners as though each partner had incurred such item directly. As a
result, each partner must take into account his pro rata share of all items of
partnership income and deductions in computing his federal income tax liability.


                                       19
<PAGE>

                 ATLAS-ENERGY FOR THE NINETIES - PUBLIC #8 LTD.
                      (A Pennsylvania Limited Partnership)

                   NOTES TO FINANCIAL STATEMENTS - (Continued)
                           December 31, 2001 and 2000


NOTE 4 - PARTICIPATION IN REVENUES AND COSTS

         Atlas and the other partners generally participate in revenues and
costs in the following manner:
<TABLE>
<CAPTION>
                                                                                               Subscribing
                                                                            Atlas               Partners
                                                                      -----------------    --------------------
<S>                                                                            <C>               <C>
          Organization and offering costs...........................           100%                   -%

          Lease costs...............................................           100%                   -%

          Revenues..................................................            29%                  71%

          Direct operating costs....................................            29%                  71%

          Intangible drilling costs.................................             -%                  100%

          Tangible costs............................................         43.75%                56.25%

          Tax deductions:

              Intangible drilling and development costs.............             -%                  100%

              Depreciation..........................................         43.75%                56.25%

              Depletion.............................................            29%                   71%
</TABLE>
NOTE 5 - TRANSACTIONS WITH ATLAS AND ITS AFFILIATES

         The Partnership has entered into the following significant transactions
with Atlas and its affiliates as provided under the Partnership agreement:

         o Administrative costs payable to Atlas at $75 per well per month.
           Administrative costs incurred in 2001 and 2000 were $52,700 and
           $35,100, respectively.

         o Monthly well supervision fees payable to Atlas at $275 per well per
           month for operating and maintaining the wells. Well supervision fees
           incurred in 2001 and 2000 were $157,300 and $104,200, respectively.

         o Transportation fees paid to Atlas of $.29 per mcf. Transportation
           costs incurred in 2001 and 2000 were $146,100 and $202,400,
           respectively.

As managing general partner, Atlas performs all administrative and management
functions for the Partnership including billing revenues and paying expenses.
Accounts Receivable-affiliate on the balance sheet represents the net production
revenues due from Atlas.

NOTE 6 - PURCHASE COMMITMENT

         Subject to certain conditions, investor partners may present their
interests beginning in 2003 for purchase by Atlas. Atlas is not obligated to
purchase more than 5% of the units in any calendar year.


                                       20
<PAGE>


                 ATLAS-ENERGY FOR THE NINETIES - PUBLIC #8 LTD.
                      (A Pennsylvania Limited Partnership)

                   NOTES TO FINANCIAL STATEMENTS - (Continued)
                           December 31, 2001 and 2000


NOTE 7 - SUBORDINATION OF MANAGING GENERAL PARTNER'S REVENUE SHARE

         Under the terms of the Partnership agreement, Atlas may be required to
subordinate a part of its partnership revenues in an amount up to 11.5% of
production revenues of the Partnership, net of related operating costs,
administrative costs and well supervision fees to the receipt by participants of
cash distributions from the Partnership equal to at least 10% of their agreed
subscriptions of $11,000,000, determined on a cumulative basis, in each of the
first five years of Partnership operations, commencing with the first
distribution of revenues to the participants. During the subordination period,
Atlas can be reimbursed for any subordination advances to the extent
distributions exceed the 10% return.

        In 2000, Atlas subordinated $76,800 of its net revenues to the other
partners, which amount was reimbursed in 2001.

NOTE 8 - INDEMNIFICATION

         In order to limit the potential liability of the investor general
partners, Atlas has agreed to indemnify each investor general partner from any
liability incurred which exceeds such partner's share of Partnership assets.

NOTE 9 - HEDGING ACTIVITIES

         Atlas enters into natural gas futures and option contracts to hedge its
exposure to changes in natural gas prices. At any point in time, such contracts
may include regulated New York Mercantile Exchange ("NYMEX") futures and options
contracts and non-regulated over-the-counter futures contracts with qualified
counter parties. NYMEX contracts are generally settled with offsetting
positions, but may be settled by the delivery of natural gas. Although hedging
provides Atlas and its affiliates, including the Partnership, some protection
against falling prices, these activities could also reduce the potential
benefits of price increases, depending upon the instrument. The Partnership does
not hold derivative instruments for trading purposes.

         Effective January 1, 2001, the Partnership adopted Statement of
Financial Accounting Standards No. 133 ("SFAS 133") Accounting for Derivative
Instruments and Hedging Activities (as amended by SFAS 138). This statement
establishes accounting and reporting standards for derivative instruments and
hedging activities. The statement requires that all derivative financial
instruments are recognized in the financial statements as either assets or
liabilities measured at fair value. Changes in the fair value of derivative
financial instruments are recognized in income or other comprehensive income,
depending on their classification. Upon adoption of SFAS 133, the Partnership
recognized the unrealized loss on derivatives designated as cash flow hedges of
$122,000 at January 1, 2001 in accumulated other comprehensive income as a
cumulative effect of accounting change.


                                       21

<PAGE>


                 ATLAS-ENERGY FOR THE NINETIES - PUBLIC #8 LTD.
                      (A Pennsylvania Limited Partnership)

                   NOTES TO FINANCIAL STATEMENTS - (Continued)
                           December 31, 2001 and 2000

NOTE 9 - HEDGING ACTIVITIES - (Continued)

         At December 31, 2001, Atlas had natural gas futures and option
contracts covering approximately 54,000 dekatherms ("Dth") of the Partnership's
gas production maturing April 2001 through September 2003 at a combined average
price of $3.25 per Dth. As these contracts qualify and have been designated as
cash flow hedges, any gains or losses resulting from market price changes are
deferred and recognized as a component of sales revenues in the month the gas is
sold. Gains or losses on futures contracts are determined as the difference
between the contract price and a reference price, generally prices on NYMEX. The
Partnership's net unrealized gain related to open NYMEX contracts was $17,900 at
December 31, 2001 and the net unrealized loss was $122,000 at December 31, 2000.
The unrealized gain of $17,900 at December 31, 2001 has been recorded as an
asset on the Partnership's 2001 Balance Sheet and in partners' capital as
accumulated other comprehensive income. As of December 31, 2001, $11,300 of the
unrealized gain is expected to be reclassified to earnings during the next 12
months. The Partnership recognized losses of approximately $76,300 and $290,000
on settled contracts covering natural gas production for the years ended
December 31, 2001 and 2000, respectively. The Partnership recognized no gains or
losses during the year ended December 31, 2001 for hedge ineffectiveness or as a
result of the discontinuance of cash flow hedges. The Partnership assesses the
effectiveness of its hedges based on changes in the derivatives' intrinsic
value.

NOTE 10 - NATURAL GAS AND OIL PRODUCING ACTIVITIES (UNAUDITED)

         The supplementary information summarized below presents the results of
natural gas and oil activities in accordance with SFAS No. 69, "Disclosures
About Oil and Gas Producing Activities".

         No consideration has been given in the following information to the
income tax effect of the activities as the Partnership is not treated as a
taxable entity for income tax purposes.

         (1)      Capitalized Costs

         The following table presents the capitalized costs related to natural
gas and oil producing activities:
<TABLE>
<CAPTION>


                                                                       =====================    ====================
                                                                               2001                    2000
                                                                       ---------------------    --------------------
<S>                                                                     <C>                       <C>
         Capitalized costs at December 31:
            Proved properties.....................................      $    12,573,800           $    12,573,800
            Accumulated depreciation and depletion................           (5,477,500)                 (990,600)
                                                                       ---------------------    --------------------

              Net capitalized costs...............................       $    7,096,300           $    11,583,200
                                                                       =====================    ====================
</TABLE>


         (2) Results of Operations for Oil and Gas Producing Activities

       The following table presents the results of operations related to natural
gas and oil production for the year ended December 31, 2001 and 2000:
<TABLE>
<CAPTION>


                                                                       =====================    ===================
                                                                               2001                    2000
                                                                       ---------------------    -------------------
<S>                                                                     <C>                       <C>
         Natural gas and oil sales................................        $   2,517,000             $  2,688,500
         Production costs.........................................             (480,100)                (419,800)
         Depreciation and depletion...............................           (4,486,800)                (990,600)
                                                                       ---------------------    -------------------
           Results of operations from producing activities........        $  (2,449,900)            $  1,278,100
                                                                       =====================    ===================
</TABLE>

                                       22
<PAGE>

                 ATLAS-ENERGY FOR THE NINETIES - PUBLIC #8 LTD.
                      (A Pennsylvania Limited Partnership)

                   NOTES TO FINANCIAL STATEMENTS - (Continued)
                           December 31, 2001 and 2000


NOTE 10 - NATURAL GAS AND OIL PRODUCING ACTIVITIES (UNAUDITED) - (Continued)

         (3) Reserve Information

         The information presented below represents estimates of proved natural
gas and oil reserves. Reserves are estimated in accordance with guidelines
established by the Securities and Exchange Commission and the Financial
Accounting Standards Board which require that reserve estimates be prepared
under existing economic and operating conditions with no provision for price and
cost escalation except by contractual arrangements. Proved reserves are
estimated quantities of oil and natural gas which geological and engineering
data demonstrate with reasonable certainty to be recoverable in future years
from known reservoirs. Proved developed reserves and are those which are
expected to be recovered through existing wells with existing equipment and
operating methods. All reserves are proved developed reserves and are located in
the Appalachian Basin area.

         There are numerous uncertainties inherent in estimating quantities of
proved reserves and in projecting future net revenues and the timing of
development expenditures. The reserve data presented represents estimates only
and should not be construed as being exact. In addition, the standardized
measures of discounted future net cash flows may not represent the fair market
value of the Partnership's oil and gas reserves or the present value of future
cash flows of equivalent reserves, due to anticipated future changes in oil and
gas prices and in production and development costs and other factors for which
effects have not been provided.
<TABLE>
<CAPTION>


                                                                       =====================    ===================
                                                                               2001                    2000
                                                                       ---------------------    -------------------
                                                                           Natural Gas             Natural Gas
                                                                              (MCF)                   (MCF)
                                                                       ---------------------    -------------------
<S>                                                                    <C>                      <C>
         Proved developed reserves:
            Beginning of period..................................              8,159,400                      -
            Production...........................................               (511,200)              (697,800)
            Current additions....................................                      -              8,857,200
            Revisions to previous estimates......................             (4,469,600)                     -
                                                                       ---------------------    -------------------
              End of period......................................              3,178,600              8,159,400
                                                                       =====================    ===================
</TABLE>

                                       23



<PAGE>



                 ATLAS-ENERGY FOR THE NINETIES - PUBLIC #8 LTD.
                      (A Pennsylvania Limited Partnership)

                   NOTES TO FINANCIAL STATEMENTS - (Continued)
                           December 31, 2001 and 2000


NOTE 10 - NATURAL GAS AND OIL PRODUCING ACTIVITIES (UNAUDITED) - (Continued)

         (4) Standard Measure of Discounted Future Cash Flows

       The standardized measure of discounted future net cash flows is
information provided for the financial statement user as a common base for
comparing oil and gas reserves of enterprises in the industry. The following
schedule presents the standardized measure of estimated discounted future net
cash flows from the Partnership's proved reserves. The estimated future
production is priced at year-end prices, adjusted only for fixed and
determinable increases in natural gas prices provided by contractual agreements.
The standardized measure of future net cash flows was prepared using the
prevailing economic conditions existing at December 31, 2001 and 2000 and such
conditions continually change. Accordingly, such information should not serve as
a basis in making any judgment on the potential value of recoverable reserves or
in estimating future results of operations.
<TABLE>
<CAPTION>


                                                                       =====================    ===================
                                                                               2001                    2001
                                                                       ---------------------    -------------------
<S>                                                                      <C>                      <C>
         Future cash inflows.....................................        $    12,678,400          $   36,071,300
         Future production costs.................................             (5,582,100)            (10,323,700)
                                                                       ---------------------    -------------------
         Future net cash flow....................................              7,096,300              25,747,600
         10% annual discount for estimated timing of cash
                flows ...........................................             (2,692,700)            (11,944,100)
                                                                       ---------------------    -------------------
         Standardized measure of discounted future net cash
              flows..............................................        $     4,403,600          $   13,803,500
                                                                       =====================    ===================
</TABLE>


         Summary of changes in the standardized measure of discounted future net
cash flows:
<TABLE>
<CAPTION>


                                                                       =====================    ===================
                                                                               2001                    2000
                                                                       ---------------------    -------------------
<S>                                                                       <C>                    <C>
         Balance, beginning of period............................         $    13,803,500        $
         Sales of gas and oil produced - net of related costs....              (2,036,900)           (2,268,700)
         Net changes in prices, production and development costs               (4,008,500)                    -
         Discoveries and extensions..............................                       -            16,072,200
         Accretion of discount...................................               1,359,000                     -
         Revision of previous quantity estimate..................              (6,227,000)                    -
         Changes in production rates and other...................               1,513,500                     -
                                                                       ---------------------    -------------------
         Balance, end of period..................................         $     4,403,600        $   13,803,500
                                                                       =====================    ===================
</TABLE>



                                       24
<PAGE>



ITEM 8. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
        FINANCIAL DISCLOSURE:

        None.

ITEM 9. DIRECTORS, EXECUTIVE OFFICERS AND SIGNIFICANT EMPLOYEES, COMPLIANCE WITH
        SECTION 16(A) OF THE EXCHANGE ACT

         Responsibilities of Atlas. We have no employees and rely on our
managing general partner, which also serves as driller-operator of the wells,
for management. Our managing general partner has complete and exclusive
discretion and control over our operations and activities and makes all of our
decisions affecting the wells we have drilled. Our managing general partner
provides continuing review and analysis of all wells and monitors all
expenditures and commitments made on our behalf. In addition, our managing
general partner performs administrative services relating to our funding and
operation, participant reporting, financial budgeting and record keeping.

         Because we have no equity securities registered pursuant to Section 12
of the Exchange Act, there is no required compliance with Section 16(A) of the
Exchange Act.

         Business of Atlas. Our managing general partner was incorporated in
1979 and its affiliate, Atlas Energy Group, Inc., an Ohio corporation which was
the first of the Atlas group of companies, was incorporated in 1973. Atlas
Energy Group serves as our operator in Ohio. As of January 1, 2002, our managing
general partner and its affiliates operated approximately 4,375 natural gas and
oil wells located in Ohio, Pennsylvania and New York.

         In September 1998, the Atlas Group, the former parent company of our
managing general partner, merged into Atlas America, Inc., a newly formed
wholly-owned subsidiary of Resource America, Inc. Resource America is a
publicly-traded company principally engaged in energy, energy finance and real
estate finance. Atlas America has and is continuing the existing business of
Atlas Group and is headquartered at 311 Rouser Road, Moon Township, Pennsylvania
15108, which is also the managing general partner's primary office.

         Officers, Directors and Key Personnel. The officers and directors of
our managing general partner will serve until their successors are elected. The
officers, directors and key personnel of our managing general partner are as
follows:

<TABLE>
<CAPTION>


NAME                             AGE      POSITION OR OFFICE
----                             ---      ------------------
<S>                              <C>      <C>
Freddie M. Kotek                 45       Chairman of the Board of Directors, Chief Executive Officer and President
Frank P. Carolas                 41       Executive Vice President - Land and Geology and a Director
Jeffrey C. Simmons               42       Executive Vice President - Operations and a Director
Michael L. Staines               51       Senior Vice President, Secretary and a Director
Nancy J. McGurk                  46       Vice President, Chief Financial Officer and Chief Accounting Officer
Jack L. Hollander                45       Vice President - Direct Participation Programs
Michael G. Hartzell              46       Vice President - Land Administration
Donald R. Laughlin               53       Vice President - Drilling and Completion
John A. Ranieri                  41       Director of Energy Sales
Louis Tierno, Jr.                38       Controller and Assistant Secretary
James R. O'Mara                  57       Director
John S. Coffey                   53       President, Secretary, Treasurer and Director of Anthem Securities, Inc.
</TABLE>


         Freddie M. Kotek. President and Chief Executive Officer since 2002 and
Chairman of the Board of Directors since 2001. Mr. Kotek is employed by Resource
America from 1993 to the present in various capacities and is currently Senior
Vice President of Resource America.

                                       25


<PAGE>



         Frank P. Carolas. Executive Vice President-Land and Geology and a
Director since January, 2001. Mr. Carolas also serves as Executive Vice
President-Land and Geology of Atlas America since January, 2001. Mr. Carolas
served as Vice President of Land and Geology for the managing general partner
from July 1999 until 2001 and for Atlas America from 1998 until 2001. Before
that Mr. Carolas served as Vice President of Atlas Group, Inc. from 1997 until
1998 which was the former parent company of the managing general partner. Mr.
Carolas is a certified petroleum geologist and has been with Atlas Energy since
1981.

         Jeffrey C. Simmons. Executive Vice President-Operations and a Director
since January, 2001. Mr. Simmons also serves as Executive Vice
President-Operations of Atlas America since January, 2001. Mr. Simmons served as
Vice President of Operations for the managing general partner from July 1999
until 2001 and for Atlas America from 1998 until 2001. Mr. Simmons joined
Resource America in 1986 as senior petroleum engineer.

         Jack L. Hollander. Vice President - Direct Participation Programs since
2001. Mr. Hollander also serves as Vice President - Direct Participation
Programs of Atlas America since 2001. Mr. Hollander began his career serving as
in house tax counsel for Integrated Resources, Inc., a large diversified
financial services company from 1982 to 1990. He then went on to practice law
with Rattet, Hollander & Pasternak with a concentration in tax matters, real
estate transactions and consulted with and assisted technology companies in
raising capital until joining the managing general partner in January 2001.

         Michael G. Hartzell. Vice President - Land Administration since 2001.
Mr. Hartzell has been with Atlas Energy since 1980.

         Donald R. Laughlin. Vice President-Drilling and Completion since 2001.
Mr. Laughlin joined Atlas America as Senior Drilling Engineer in May, 2001. He
has over thirty years of experience in the Appalachian Basin and before joining
Atlas America was with Columbia Gas Transmission Corporation from 1995 to 2001.

         Louis Tierno, Jr. Controller and Assistant Secretary since May 2001.
Mr. Tierno also serves as Controller of Atlas America since May 2001. Mr. Tierno
has over 15 years of finance, accounting, tax and administrative experience in
the oil and gas industry with Angerman Associates, Inc. which was engaged in the
oil and gas business, as Director of Accounting/Financial Operations from 1984
until March 1998. Beginning April 1998 until October 1999 he was Vice President
of Finance for the Baron Group, an oil and gas company. He joined CFS Americas,
Inc., a software company, as Controller in November 1999 until December 2000 and
served as a consultant to CFS Americas, Inc. from January 2001 until April 2001
when he joined Atlas America and the managing general partner.

Key Personnel.

         Michael L. Staines. Senior Vice President, Secretary and a Director
since 1998. Mr. Staines is also Executive Vice President, Secretary and a
Director of Atlas America since 1998, Senior Vice President of Resource America
since 1989, Secretary of Resource America from 1989 to 1998, Director of
Resource America from 1989 to 2000, President, Secretary and a Director of
Resource Energy, an energy subsidiary of Resource America, since 1993, President
of Atlas Pipeline Partners GP, LLC since 2001, and Chief Operating Officer,
Secretary and Managing Board Member of Atlas Pipeline Partners GP, LLC since its
formation in 1999.

         Nancy J. McGurk. Vice President, Chief Financial Officer and Chief
Accounting Officer since January, 2001. Ms. McGurk also serves as Vice
President, Chief Financial Officer and Chief Accounting Officer of Atlas America
and has been Vice President of Resource America since 1992. Before that she had
served as Treasurer and Chief Accounting Officer of Resource America since 1989.
Also, since 1995 Ms. McGurk has served as Vice President - Finance of Resource
Energy.

         John A. Ranieri. Director of Energy Sales since 2001 and before that
Director of Gas Marketing for nine years.

                                       26
<PAGE>


         James R. O'Mara. A Director since 1980. Mr. O'Mara served as President
and Chief Executive Officer of our managing general partner from 1999 until he
retired in January 2002 and Vice Chairman and a Director of Atlas America from
2001 until his retirement. Mr. O'Mara joined Atlas Energy in 1975.

         John S. Coffey. President, Secretary, Treasurer and Director of Anthem
Securities, Inc. Mr. Coffey joined Anthem Securities, Inc. in May 2000. He was
previously associated with Financial Investment Analysts, Inc. from November
1984 to May 2000.



                                       27


<PAGE>



                                    PART III


ITEM 10. EXECUTIVE COMPENSATION

         We have no employees and rely on the employees of our managing general
partner and its affiliates for services. Thus, we did not directly pay any
compensation to the employees of our managing general partner for the last
fiscal year. See Item 12, "Certain Relationships and Related Transactions,"
below for compensation paid to our managing general partner.

ITEM 11. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT

         As of December 31, 2001, we had issued and outstanding 1111 units. No
officer or director of our managing general partner owns any units. Also, no
partner beneficially owns more than 10% of our outstanding units.

         Resource America owns 100% of the common stock of Atlas America, which
owns 100% of the common stock of AIC, Inc., which owns 100% of the common stock
of our managing general partner.

ITEM 12. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS

       Oil and Gas Revenues. Our managing general partner is allocated 29% of
our oil and gas revenues in return for having paid organization and offering
costs equal to 15% of our subscriptions, 43.75% of tangible costs and
contributing all leases for a total capital contribution of $3,148,200. During
the calendar years ending December 31, 2001 and December 31, 2000, our managing
general partner received $590,700 and $657,900, respectively, from our net
production revenues.

       Leases. On the initial closing date as amended on the final closing date
our managing general partner contributed to us 58 undeveloped prospects to drill
approximately 54.66 net wells and received a credit in the amount of $198,000.
During 2001 and 2000, our managing general partner did not enter into any
further lease transactions with us and none are anticipated.

       Administrative Costs. Our managing general partner and its affiliates
receive an unaccountable, fixed payment reimbursement for their administrative
costs of $75 per well per month, which is proportionately reduced if we acquired
less than 100% of the working interest in a well. During the calendar years
ending December 31, 2001 and December 31, 2000, our managing general partner
received $52,700 and $35,100, respectively, for its administrative costs.

       Direct Costs. Our managing general partner and its affiliates are
reimbursed for all direct costs expended on our behalf. During the calendar
years ending December 31, 2001 and December 31, 2000, our managing general
partner received $176,700 and $113,200, respectively, as reimbursement for
direct costs.

       Drilling Contracts. On the initial closing date as amended on the final
closing date, we entered into a drilling contract with our managing general
partner to drill and complete 54.66 net wells. The total amount received by our
managing general partner was $11,089,000 for drilling and completing the wells.
During 2001 and 2000, we did not enter into any further drilling transactions
and none are anticipated.

       Per Well Charges. Our managing general partner, as operator, is
reimbursed at actual cost for all direct expenses incurred on our behalf and
receives well supervision fees for operating and maintaining the wells during
producing operations in the amount of $275 per well per month subject to an
annual adjustment for inflation. During the calendar years ending December 31,
2001 and December 31, 2000, our managing general partner received $157,300 and
$104,200, respectively, for well supervision fees.

                                       28
<PAGE>


         Gathering Fees. We pay a combined gathering fee at a competitive rate
for each mcf transported to Atlas Pipeline Partners, L.P., for natural gas which
we produce. For the calendar years ending December 31, 2001 and December 31,
2000, we paid $146,100 and $202,400, respectively.

         Other Compensation. For the calendar years ending December 31, 2001 and
December 31, 2000, our managing general partner did not advance any funds nor
did it provide any equipment, supplies or other services.

ITEM 13. EXHIBITS AND REPORTS ON FORM 8-K

         We have not filed any reports on Form 8-K during the last quarter of
the period covered by this report. For certain exhibits see exhibit index on
page 31.




                                       29

<PAGE>


                                   SIGNATURES

        In accordance with Section 13 or 15(d) of the Exchange Act, the
registrant caused this report to be signed on its behalf by the undersigned,
thereunto duly authorized.

<TABLE>
<CAPTION>

Atlas-Energy for the Nineties Public #8 Ltd.
<S>                                 <C>
By:  (Signature and Title):         Atlas Resources, Inc., Managing General Partner

By   (Signature and Title):
                                    -----------------------------------------------------------------------------------
                                    Freddie M. Kotek, Chairman of the Board of Directors,
                                    Chief Executive Officer and President

Date:  April 1, 2002


        In accordance with the Exchange Act, this report has been signed by the
following persons on behalf of the registrant and in the capacities and on the
dates indicated.


By  (Signature and Title):
                                    -----------------------------------------------------------------------------------
                                    Freddie M. Kotek, Chairman of the Board of Directors,
                                    Chief Executive Officer and President

Date:  April 1, 2002


By  (Signature and Title):
                                    -----------------------------------------------------------------------------------
                                    Frank P. Carolas, Executive Vice President-Land and
                                    Geology and a Director
Date:  April 1, 2002


By  (Signature and Title):
                                    -----------------------------------------------------------------------------------
                                    Jeffrey C. Simmons, Executive Vice President-Operations and a Director
Date:  April 1, 2002

By  (Signature and Title):
                                    -----------------------------------------------------------------------------------
                                    Nancy J. McGurk, Vice President, Chief Financial Officer and
                                    Chief Accounting Officer
Date:  April 1, 2002
</TABLE>


                    Supplemental information to be Furnished
                  With Reports Filed Pursuant to Section 15(d)
                  of the Exchange Act by Non-reporting Issuers

An annual report will be furnished to security holders subsequent to the filing
of this report.

                                       30

<PAGE>





                                  EXHIBIT INDEX

<TABLE>
<CAPTION>

                             Description                               Location
                             -----------                               --------
<S>        <C>                                                         <C>
4(a)       Certificate of Limited Partnership for                      Previously filed in the Form
           Atlas-Energy for the Nineties-Public #8 Ltd.                10-KSB for the period ending
                                                                       December 31, 1999

4(b)       Amended and Restated Certificate and Agreement              Previously filed in the Form
           of Limited Partnership for Atlas-Energy for the             10-KSB for the period ending
           Nineties-Public #8 Ltd.                                     December 31, 1999

10(a)      Drilling and Operating Agreement with exhibits              Previously filed in the Form
                                                                       10-KSB for the period ending
                                                                       December 31, 1999


</TABLE>
                                       31