<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, 2002

             [ ] 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. $1,174,400

         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>
PART I                                                                                                           Page
<S>             <C>                                                                                          <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................................................................   11-13
     Item 7:    Financial Statements and Supplementary Data..................................................   14-25
     Item 8:    Changes in and Disagreements with Accountants
                    on Accounting and Financial Disclosure...................................................      25

PART III

     Item 9:    Directors, Executive Officers and Significant Employees,
                    Compliance with Section (16A) of the Exchange Act........................................   26-29
     Item 10:   Executive Compensation.......................................................................      29
     Item 11:   Security Ownership of Certain Beneficial Owners and Management...............................      29
     Item 12:   Certain Relationships and Related Transactions...............................................      30
     Item 13:   Exhibits and Reports on Form 8-K.............................................................      30
     Item 14:   Controls and Procedures......................................................................      31


SIGNATURES...................................................................................................      33

CERTIFICATIONS...............................................................................................   34-35

</TABLE>


                                       2
<PAGE>

                                     PART I

ITEM 1. DESCRIPTION OF BUSINESS

         General. We were formed as a Pennsylvania limited partnership on June
18, 1999, with Atlas Resources, Inc. 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 3, 1999, and our final closing date was December 31, 1999. 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.

         Business Strategy. Our wells are currently producing natural gas and to
a far lesser extent oil, which are our only products. Most of our gas is
gathered and delivered to market through Atlas Pipeline Partners' gas gathering
system, which is managed by an affiliate of our managing general partner. We do
not plan to sell any of our wells and will continue to produce them until they
are depleted at which time they will be plugged and abandoned. No other wells
will be drilled and 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 the sale of our gas and oil production. We
pay our managing general partner a monthly well supervision fee of $275 per
well, as outlined in our drilling and operating agreement. This well supervision
fee covers all normal and regularly recurring operating expenses for the
production and sale of gas and to a lesser extent oil, 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 certain equipment, materials 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, per well to cover the
estimated future plugging and abandonment costs. As of December 31, 2002 the
managing general partner has not withheld such funds.



                                       3
<PAGE>

         Markets and Competition. The availability of a ready market for natural
gas and oil produced by us, and the price obtained, depends upon numerous
factors beyond our control, including the extent of domestic production, import
of foreign natural gas and oil, political instability in oil and gas producing
countries and regions, market demand, the effect of federal regulation on the
sale of natural gas and oil in interstate commerce, other governmental
regulation of the production and transportation of natural gas and oil and the
proximity, availability and capacity of pipelines and other required facilities.
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. During 2002 and 2001, we experienced no problems in
selling our natural gas and oil under these commitments, although prices we
received varied during and after the period, sometimes significantly. Product
availability and price are the principal means of competition in selling natural
gas and oil production. While it is impossible to accurately determine our
comparative position in the industry, we do not consider our operations to be a
significant factor in the industry. Without the commitments discussed in Item 2,
Properties - Delivery Commitments our managing general partner may sell our gas
through similar commitments to other purchasers or at existing spot market
prices.

         Governmental Regulation. The energy industry in general is heavily
regulated by federal and state authorities, including regulation of production,
environmental quality and pollution control. The intent of federal and state
regulations generally is to prevent waste, protect rights to produce natural gas
and oil between owners in a common reservoir and control contamination of the
environment. Failure to comply with regulatory requirements can result in
substantial fines and other penalties. The following discussion of the
regulations of the United States energy industry does not intend to constitute a
complete discussion of the various statutes, rules, regulations and
environmental orders to which our operations may be subject.

         Regulation of oil and gas producing activates. State regulatory
agencies where a producing natural gas well is located provide 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>


         Environmental and Safety Regulation. Under the Comprehensive
Environmental Response, Compensation and Liability Act, the Toxic Substances
Control Act, the Resource Conservation and Recovery Act, the Oil Pollution Act
of 1990, the Clean Air Act, and other federal and state laws relating to the
environment, owners and operators of wells producing natural gas or oil, and
pipelines, can be liable for fines, penalties and clean-up costs for pollution
caused by the wells or the pipelines. Moreover, the owners' or operators'
liability can extend to pollution costs from situations that occurred prior to
their acquisition of the assets. Natural gas pipelines are also subject to
safety regulation under the Natural Gas Pipeline Safety Act of 1968 and the
Pipeline Safety Act of 1992 which, among other things, dictate the type of
pipeline, quality of pipeline, depth, methods of welding and other
construction-related standards. State public utility regulators in Ohio and
Pennsylvania have either adopted federal standards or promulgated their own
safety requirements consistent with the federal regulations.

         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 not mentioned, including those 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, currently we do not believe these costs will be substantial.
However, we cannot predict the ultimate costs of complying with present and
future environmental laws and regulations because these laws and regulations are
constantly being revised and ultimately may have a material impact to our
operations to remain in compliance. Additionally, we cannot obtain insurance to
protect against many types of environmental claims.

Where can you find more information. We file Form 10KSB Annual Report and Form
10QSB Quarterly Report as well as other non-recurring special purpose reports
with the Securities and Exchange Commission. A complete list of our filings is
available on the Securities and Exchange Commission's website at WWW.SEC.GOV.
Any of our filings are also available at the SEC's Public Reference Room at 450
Fifth Street, N.W., Washington, D.C. 20549. The Public Reference Room may be
contacted at 1-800- SEC-0330 for further information.

Additionally, our Managing General Partner will provide you copies of any of
these reports without charge. Such requests should be made to:

                  Atlas-Energy for the Nineties-Public #8 Ltd.
                                 311 Rouser Road
                             Moon Township, PA 15108


ITEM 2.  PROPERTIES

         Drilling Activity. For the years ended December 31, 2002 and 2001,
respectively, we did not drill any wells nor do we expect to do so in future
years.

         Summary of Productive Wells. The table below shows the number of our
productive gross and net wells by state at December 31, 2002 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
                                              -------            ------


                                       5
<PAGE>



         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
                                  Production                       Average Sales Price           Cost (Lifting Cost)
                                                                                                   per mcfe (1) (2)
 Year                   ----------------------------------    --------------------------------      ---------------
Ended                     Oil (bbls)     Gas (mcf)               per bbl         per mcf
------                    ----------     ---------               -------         -------

<S>                           <C>            <C>                  <C>             <C>                    <C>
 2002............             200            343,000              $ 18.59         $  3.41                $   .86
 2001............               -            511,200              $  -            $  4.92                $   .94
</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.

         Natural Gas and Oil Reserve Information. The following tables summarize
 information regarding our estimated proved natural gas and oil reserves as of
 the dates indicated. All of our reserves are located in the United States. We
 base our estimates relating to our proved natural gas and oil reserves and
 future net revenues of natural gas and oil reserves upon reports prepared by
 Wright & Company, Inc. In accordance with SEC guidelines, we make the
 standardized and SEC PV-10 estimates of future net cash flows from proved
 reserves using natural gas and oil sales prices in effect as of the dates of
 the estimates which are held constant throughout the life of the properties. We
 based our estimates of proved reserves upon the following weighted average
 prices:

                                                   At December 31
                                        -------------------------------------
                                             2002                 2001
                                        ----------------    -----------------
Natural gas (per mcf).............        $    3.70           $    3.99
Oil (per bbl).....................        $   26.75           $      -


         Reserve estimates are imprecise and may change as additional
information becomes available. Furthermore, estimates of natural gas and oil
reserves, of necessity, are projections based on engineering data. 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.
Reserve reports of other engineers might differ from the reports of our
consultants, Wright & Company. Results of drilling, testing and production
subsequent to 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 estimated by Wright & Company in preparing its reports. The amounts
and timing of future operating and development costs may also differ from those
used. Accordingly, the reserves set forth in the following tables ultimately may
not be produced and the proved undeveloped reserves may not be developed within
the periods anticipated. You should not construe the estimated PV-10 values as
representative of the fair market value of our proved natural gas and oil
properties. PV-10 values are based upon projected cash inflows, which do not
provide for changes in natural gas and oil prices or for escalation of expenses
and capital costs. The meaningfulness of these estimates depends upon the
accuracy of the assumptions upon which they were based.



                                       6
<PAGE>


         We evaluate natural gas reserves at constant temperature and pressure.
A change in either of these factors can affect the measurement of natural gas
reserves. We deducted when applicable, operating costs, development costs and
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 conditions prevailing as of the dates indicated. 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. For additional
information concerning our natural gas and oil reserves and estimates of future
net revenues, see notes to our Financial Statements.



<TABLE>
<CAPTION>

                                                                          At December 31
                                                                 ----------------------------------
                                                                     2002                2001
                                                                 --------------      --------------
<S>                                                             <C>                 <C>
Natural gas reserves - Proved Reserves (Mcf)(1):
   Proved developed reserves (2)..........................           2,527,600           3,168,100
   Proved undeveloped reserves (3)........................                   -                   -
                                                                 --------------      --------------
     Total proved reserves of natural gas.................           2,527,600           3,168,100

Oil reserves: - Proved Reserves (Bbl)(1)
   Proved developed reserves (2)..........................              2,500               1,700
   Proved undeveloped reserves (3)........................                    -                 -
                                                                 --------------      --------------
     Total proved reserves of oil.........................              2,500                   -
                                                                 --------------      --------------

       Total proved reserves (Mcfe).......................           2,542,600           3,178,600
                                                                 ==============      ==============

PV-10 estimate of cash flows of proved reserves (4):
   Proved developed reserves..............................       $   2,991,400       $   4,403,600
   Proved undeveloped reserves............................                    -                  -
                                                                 --------------      --------------
     Total PV-10 estimate.................................       $   2,991,400       $   4,403,600
                                                                 ==============      ==============
</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.



                                       7
<PAGE>

         We have not filed any estimates 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. We believe that we hold good and indefeasible
title to our properties, in accordance with standards generally accepted in the
natural gas industry, subject to exceptions stated in the opinions of counsel
employed by us in the various areas in which we conduct our activities. We do
not believe that these exceptions detract substantially from our use of any
property. As is customary in the natural gas industry, we conduct only a
perfunctory title examination at the time we acquire a property. Before we
commence drilling operations, we conduct an extensive title examination and we
perform curative work on defects that we deem significant. We have obtained
title examinations for substantially all of our managed producing properties. No
single property represents a material portion of our holdings.

         Our properties are subject to royalty, overriding royalty and other
outstanding interests customary in the industry. Our properties are also subject
to burdens such as liens incident to operating agreements, taxes, development
obligations under natural gas and oil leases, farm-out arrangements and other
encumbrances, easements and restrictions. We do not believe that any of these
burdens will materially interfere with our use of our properties.


         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, 2002.

<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 with the exception of the
gas that is being sold to 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.



                                       8
<PAGE>

       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.

         Pricing for gas and oil production has been volatile and unpredictable
for many years. To hedge exposure to changing natural gas prices our managing
general partner uses financial hedges. In addition, our contract with First
Energy Solutions Corporation, a full service gas marketer, permits us, at our
managing general partner's discretion, to designate a portion of our production
to be delivered at a future date within the contract terms, at current market
prices. However, these transactions are not derivatives to us. We essentially
are locking in the sale price of our gas with First Energy prior to it being
produced. Once designated we, cannot offset our position under the contract and
are required to deliver the production to the delivery point. 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
agreements, may be significantly different than the underlying monthly spot
market value in the month the gas is produced. With respect to financial hedges,
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, procedures and
risk management objectives. 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.


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, 2002, we had 387 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 which our managing general
partner determines are not necessary for us to retain to our partners and the
other participants. 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 years ended December 31, 2002 and 2001,
respectively, we distributed the following:

         o        $606,100 and $1,763,500 to our limited partners; and

         o        $ 247,600 and $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-KSB 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 sets 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,
                                                                 -------------------------------
                                                                      2002             2001
                                                                 --------------   --------------
<S>                                                             <C>              <C>
Revenues (in thousands):
     Gas(1)...............................................       $       1,169    $       2,517
     Oil..................................................       $           4                -
Production volumes:
     Gas (thousands of cubic feet (mcf)/day)..............                 940            1,401
     Oil (barrels (bbls)/day).............................                   1                -
Average sales price:
     Gas (per mcf)........................................       $        3.41    $        4.92
     Oil (per bbl)........................................       $       18.59    $           -
Production costs:
     As a percent of sales................................                 25%              19%
     Per equivalent mcf...................................       $         .86    $         .94
</TABLE>


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

         Revenues. Our production revenues for the year ended December 31, 2002
were $1,172,800, a decrease of $1,344,200 (53%) from $2,517,000 for the year
ended December 31, 2001. The decrease was substantially due to a $1.51 per mcf
decrease (31%) in the average sales price for natural gas coupled with a 168,200
mcf decrease (33%) in annual production volumes. The decrease of $1,344,200
consisted of $775,100 attributable to natural gas price decreases and $573,100
attributable to natural gas volume decreases, partially offset by increases in
oil.

         The price we receive for our natural gas is primarily a result of the
index driven agreement with First Energy Services Corporation (see Item 2
Properties - Delivery Commitments). As such, the price we receive for our
natural gas may vary significantly each month as the underlying index changes in
response to market conditions. The decrease in gas production volumes results
primarily from the natural production decline inherent in the life of our wells.



                                       11
<PAGE>


         Expenses. Production expenses for the year ended December 31, 2002 were
$296,000 compared to $480,100 for the year ended December 31, 2001, a decrease
of $184,100 (38%). The decrease is primarily attributable to lower production
volumes and the related decrease in costs associated with that production for
the year ended December 31, 2002 compared to the same period ended 2001.

         Depletion and depreciation of oil and gas properties as a percentage of
oil and gas revenues was 68% for the year ended December 31, 2002 compared to
62% for the year ended December 31, 2001. This percentage change is directly
attributable to changes in our oil and gas reserve quantities, product prices,
production and fluctuations in the depletable cost basis of oil and gas
properties.

         Impairment of oil and gas properties for year ended December 31, 2002
was $1,429,000 compared to $2,937,700 for the year ended December 31, 2001.
Annually, we compare the carrying value of our proved developed oil and gas
producing properties to their estimated fair market value. To the extent our
carrying value exceeds the estimated fair market value an impairment charge is
recognized.

         General and Administrative expenses for the year ended December 31,
2002 amounted to $78,500 compared to $81,700 for the year ended December 31,
2001, a decrease of $3,200 (4%). The decrease was due to lower charges incurred
for certain outside services.

         Liquidity and Capital Resources. Cash provided by operating activities
decreased $1,756,300 most of which was due to a $1.51 per mcf decrease (31%) in
the average sales price for natural gas coupled with a 168,200 mcf decrease
(33%) in annual production volumes.

         No cash was either provided by or used for investing activities for
both the years ended December 31, 2002 and 2001. We had no new material
commitments to make capital expenditures during the periods and we do not expect
any in the foreseeable future, except that our managing general partner may
withhold funds for future plugging and abandonment costs. 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.

         Cash used by financing activities decreased $1,738,300 to $853,700 for
the year ended December 31, 2002 compared to the year ended December 31, 2001.
The decrease is directly related to lower distributions to partners as a result
of decreases in the price we received for our natural gas and the volumes
produced.

         Recently issued Financial Accounting Standards. In July 2001, the
Financial Accounting Standards Board issued SFAS 143, "Accounting for Asset
Retirement Obligations", which establishes requirements for the accounting for
removal costs associated with asset retirements. SFAS 143 is effective for
fiscal years beginning after June 15, 2002, and will require us to record a
liability for our retirement obligations with the related transition adjustment
reported as a cumulative affect of a change in accounting principle. We are
currently assessing the impact of SFAS 143 on our consolidated financial
statements.



                                       12
<PAGE>

         Critical Accounting Policies. The discussion and analysis of our
financial condition and results of operations are based upon our financial
statements, which have been prepared in accordance with accounting principles
generally accepted in the United States. The preparation of these financial
statements requires us to make estimates and judgments that affect the reported
amounts of our assets, liabilities, revenues and cost and expenses, and related
disclosure of contingent assets and liabilities. On an on-going basis, we
evaluate our estimates, including those related to oil and gas reserves and
certain accrued liabilities. We base our estimates on historical experience and
on various other assumptions that we believe reasonable under the circumstances,
the results of which form the basis for making judgments about the carrying
values of assets and liabilities that are not readily apparent from other
sources. Actual results may differ from these estimates under different
assumptions or conditions.

         We have identified the following policies as critical to our business
operations and the understanding of our results of operations. For a detailed
discussion on the application of these and other accounting policies, see Note 2
of the "Notes to Financial Statements" in Item 7 of this report.

         Reserve Estimates Our estimates of our proved natural gas and oil
reserves and future net revenues from them are based upon reserve analyses that
rely upon various assumptions, including those required by the SEC, as to
natural gas and oil prices, drilling and operating expenses, capital
expenditures, taxes and availability of funds. Any significant variance in these
assumptions could materially affect the estimated quantity of our reserves. As a
result, our estimates of our proved natural gas and oil reserves are inherently
imprecise. Actual future production, natural gas and oil prices, revenues,
taxes, development expenditures, operating expenses and quantities of
recoverable natural gas and oil reserves may vary substantially from our
estimates or estimates contained in the reserve reports. In addition, our proved
reserves may be subject to downward or upward revision based upon production
history, results of future exploration and development, prevailing natural gas
and oil prices, mechanical difficulties, governmental regulation and other
factors, many of which are beyond our control.

         Impairment of Oil and Gas Properties We review our producing oil and
gas properties for impairment on an annual basis and whenever events and
circumstances indicate a decline in the recoverability of their carrying values.
We estimate the expected future cash flows from our oil and gas properties and
compare such future cash flows to the carrying amount of the oil and gas
properties to determine if the carrying amount is recoverable. If the carrying
amount exceeds the estimated undiscounted future cash flows, we will adjust the
carrying amount of the oil and gas properties to their fair value in the current
period. The factors used to determine fair value include, but are not limited
to, estimates of reserves, future production estimates, anticipated capital
expenditures, and a discount rate commensurate with the risk associated with
realizing the expected cash flows projected. Given the complexities associated
with oil and gas reserve estimates and the history of price volatility in the
oil and gas markets, events may arise that will require us to record an
impairment of our oil and gas properties and there can be no assurance that such
impairments will not be required in the future.





                                       13
<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, 2002
and 2001, 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, 2002 and 2001 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.








Cleveland, Ohio
February 28, 2003





                                       14
<PAGE>


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

                                 BALANCE SHEETS

<TABLE>
<CAPTION>
                                                           December 31,
                                                      2002              2001
                                                   ------------    ------------
<S>                                                <C>             <C>
                             ASSETS
Current assets:
Cash ...........................................   $      1,600    $     19,700
Accounts receivable - affiliate ................        119,500         136,600
Unrealized hedging gains .......................           --            17,900
                                                   ------------    ------------
      Total current assets .....................        121,100         174,200

Oil and gas properties (successful efforts) ....     12,573,800      12,573,800
   Less accumulated depletion and depreciation .     (7,704,400)     (5,477,500)
                                                   ------------    ------------
                                                      4,869,400       7,096,300
                                                   ------------    ------------
                                                   $  4,990,500    $  7,270,500
                                                   ============    ============


               LIABILITIES AND PARTNERS' CAPITAL
Current liabilities:
Accrued liabilities                                $     18,600    $       --
Unrealized hedging losses                                52,700            --
                                                   ------------    ------------
   Total current liabilities                             71,300            --
Partners' capital:
   Managing General Partner ....................        593,200         872,000
   Limited Partners (1,111 units) ..............      4,378,700       6,380,600
   Accumulated other comprehensive income (loss)        (52,700)         17,900
                                                   ------------    ------------
                                                      4,919,200       7,270,500
                                                   ------------    ------------
                                                   $  4,990,500    $  7,270,500
                                                   ============    ============
</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 OPERATIONS


<TABLE>
<CAPTION>
                                                                           Years Ended
                                                                           December 31,
                                                                    2002                 2001
                                                               --------------       ---------------
<S>                                                            <C>                  <C>
REVENUES
Natural gas and oil sales.................................     $    1,172,800       $     2,517,000
Interest income...........................................              1,600                11,000
                                                               --------------       ---------------
      Total revenues......................................          1,174,400             2,528,000

COSTS AND EXPENSES
Production expenses.......................................            296,000               480,100
Depletion and depreciation of oil and gas properties......            797,900             1,549,100
Impairment of oil and gas properties......................          1,429,000             2,937,700
General and administrative expenses.......................             78,500                81,700
                                                               --------------       ---------------
         Total expenses...................................          2,601,400             5,048,600
                                                               --------------       ---------------
               NET LOSS                                        $   (1,427,000)      $    (2,520,600)
                                                               ==============       ===============


Allocation of net earnings (loss):
   Managing General Partner...............................     $      (31,200)      $       116,700
                                                               ==============       ===============
   Limited Partners.......................................     $   (1,395,800)      $    (2,637,300)
                                                               ==============       ===============
       Net loss per limited partnership unit..............     $       (1,256)      $        (2,374)
                                                               ==============       ===============
</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 CHANGES IN PARTNERS' CAPITAL ACCOUNTS
                     YEARS ENDED DECEMBER 31, 2002 AND 2001


<TABLE>
<CAPTION>
                                                                                     Accumulated
                                                        Managing                        Other
                                                        General        Limited      Comprehensive
                                                        Partner        Partners     Income (loss)        Total
                                                       ------------    ------------    ------------    ------------
<S>                                                    <C>             <C>             <C>             <C>
Balance at January 1, 2001 .........................   $  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 oil and gas properties ......       (347,300)     (2,590,400)           --        (2,937,700)
         General and administrative ................        (23,700)        (58,000)           --           (81,700)
                                                       ------------    ------------    ------------    ------------
             Net earnings (loss) ...................        166,600      (2,637,200)           --        (2,520,600)

    Cumulative effect of accounting change .........           --              --          (122,000)       (122,000)
    Cash flow hedge losses reclassified to gas sales           --              --            76,300          76,300
    Change in fair value of cash flow hedges .......           --              --            63,600          63,600

            Comprehensive loss .....................                                                     (2,502,700)

    Distributions ..................................       (828,500)     (1,763,500)           --        (2,592,000)
                                                       ------------    ------------    ------------    ------------

Balance at December 31, 2001 .......................   $    872,000    $  6,380,600    $     17,900    $  7,270,500
                                                       ------------    ------------    ------------    ------------

Comprehensive income (loss):
    Participation in revenue and expenses:
         Net production revenues ...................        254,300         622,500            --           876,800
         Interest income ...........................            500           1,100            --             1,600
         Depletion and depreciation ................        (94,300)       (703,600)           --          (797,900)
         Impairment of oil and gas properties ......       (168,900)     (1,260,100)           --        (1,429,000)
         General and administrative ................        (22,800)        (55,700)           --           (78,500)
                                                       ------------    ------------    ------------    ------------
             Net loss ..............................        (31,200)     (1,395,800)           --        (1,427,000)
    Cash flow hedge losses reclassified to gas sales           --              --            14,600          14,600
    Change in fair value of cash flow hedges .......           --              --           (85,200)        (85,200)
                                                                                                       ------------
         Comprehensive loss ........................                                                     (1,497,600)
    Distributions ..................................       (247,600)       (606,100)           --          (853,700)
                                                       ------------    ------------    ------------    ------------

Balance at December 31, 2002 .......................   $    593,200    $  4,378,700    $    (52,700)   $  4,919,200
                                                       ============    ============    ============    ============

</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)

                            STATEMENTS OF CASH FLOWS


<TABLE>
<CAPTION>
                                                                                         Years Ended
                                                                                        December 31,
                                                                                     2002           2001
                                                                                 -----------    -----------
<S>                                                                          <C>                <C>
Cash flows from operating activities:

Net loss.....................................................................    $(1,427,000)   $(2,520,600)

 Adjustments to reconcile net loss to net cash provided by
  operating activities:

  Impairment of oil and gas properties .......................................     1,429,000      2,937,700

  Depletion and depreciation .................................................       797,900      1,549,100

  Decrease in accounts receivable - affiliate ................................        17,100        438,300

  Increase in accrued liabilities ............................................        18,600        187,400
                                                                                 -----------    -----------


Net cash provided by operating activities ....................................       835,600      2,591,900


Cash flows from financing activities:

Capital distributions ........................................................      (853,700)    (2,592,000)
                                                                                 -----------    -----------


Net cash used in financing activities ........................................      (853,700)    (2,592,000)
                                                                                 -----------    -----------

Net decrease in cash .........................................................       (18,100)          (100)

Cash at beginning of year ....................................................        19,700         19,800
                                                                                 -----------    -----------

Cash at end of year..........................................................    $     1,600    $    19,700
                                                                                 ===========    ===========

</TABLE>






    The accompanying notes are an integral part of these financial statements


                                       18
<PAGE>


                 Atlas-Energy for the Nineties - Public #8 Ltd.
                      (A Pennsylvania Limited Partnership)
                          NOTES TO FINANCIAL STATEMENTS
                                December 31, 2002

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 387
Limited Partners. The Partnership was formed on June 18, 1999 to drill and
operate gas wells located primarily in Western Pennsylvania. At December 31,
2002, the Partnership had various working interests in 58 gross 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 fair
market value in order to determine whether their carrying values should be
reduced. As a result of this assessment, impairment losses of $1,429,000 and
$2,937,700 were recognized in 2002 and 2001, respectively.

        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, 2002 and 2001, the
Partnership estimated that equipment salvage values would be sufficient to
recover the estimated costs of future dismantlement, restoration, reclamation,
and abandonment. However, should these estimated costs exceed the estimated
salvage values, beginning three years after each well has been placed into
production the managing general partner, as operator, may retain $200 of
production revenues per month, per well to cover estimated future plugging and
abandonment costs.




                                       19
<PAGE>

                 Atlas-Energy for the Nineties - Public #8 Ltd.
                      (A Pennsylvania Limited Partnership)
                         NOTES TO FINANCIAL STATEMENTS
                               December 31, 2002

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 on its financial statements.

Major Customers

        Substantially all of the Partnership's revenues were derived from sales
to First Energy Solutions Corporation. However, the market for gas and oil
production is a diverse open market and other purchasers are readily available.



                                       20
<PAGE>

                 Atlas-Energy for the Nineties - Public #8 Ltd.
                      (A Pennsylvania Limited Partnership)
                         NOTES TO FINANCIAL STATEMENTS
                               December 31, 2002

NOTE 2 -  SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

         Hedging Activities

         Atlas uses natural gas futures and option contracts to hedge its
exposure to changes in natural gas prices. The partnership accounts for its
portion of the hedging activates under Statements of Financial Accounting
Standards No. 133 ("SFAS 133") Accounting for Derivative Instruments and Hedging
Activates (as amended by SFAS 138). These contracts qualify and have been
designated as cash flow hedges under SFAS 133 and accordingly, gains and losses
resulting from market price changes are deferred and recognized as a component
of sales revenues in the month the gas is sold.

        Comprehensive Income

         Comprehensive income includes net income and all other changes in the
equity of a business during a period from transactions and other events and
circumstances from non-owner sources. These changes, other than net income, are
referred to as "other comprehensive income" and for the partnership represent
unrealized hedging gains and losses.

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.

NOTE 4 - PARTICIPATION IN REVENUES AND COSTS

        The Managing General Partner and the other partners generally
participate in revenues and costs in the following manner:


                                             Managing
                                             General        Other
                                             Partner       Partners
                                             ---------      ------

Organization and offering costs                 100%           0%
Lease costs                                     100%           0%
Revenues                                         29%          71%
Operating costs, administrative costs,
  direct costs and all other costs               29%          71%
Intangible drilling costs and depletion           0%         100%
Tangible costs and depreciation               43.75%       56.25%





                                       21
<PAGE>

                 Atlas-Energy for the Nineties - Public #8 Ltd.
                      (A Pennsylvania Limited Partnership)
                          NOTES TO FINANCIAL STATEMENTS
                                December 31, 2002


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:

        Administrative costs payable to Atlas at $75 per well per month.
        Administrative costs incurred in 2002 and 2001 were $47,500 and $52,700,
        respectively.

        Monthly well supervision fees payable to Atlas at $275 per well per
        month for operating and maintaining the wells. Well supervision fees
        incurred in 2002 and 2001 were $144,200 and $157,300, respectively.

        Transportation fees paid to Atlas at $.29 per mcf. Transportation costs
        incurred in 2002 and 2001 were $67,500 and $146,100, respectively.

        As the 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 2004 for purchase by Atlas. Atlas is not obligated to
purchase more than 5% of the units in any calendar year.

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 approximately $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 (June 2000). During the
subordination period, Atlas can be reimbursed for any subordination advances to
the extent distributions exceed the 10% return. In 2002 and 2001, Atlas was not
required to subordinate any of its net revenues to the other partners.

NOTE 8 - 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.



                                       22
<PAGE>

                 Atlas-Energy for the Nineties - Public #8 Ltd.
                      (A Pennsylvania Limited Partnership)
                         NOTES TO FINANCIAL STATEMENTS
                               December 31, 2002

NOTE  8 - HEDGING ACTIVITIES (Continued)

        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.

        At December 31, 2002, Atlas had natural gas futures and option contracts
covering approximately 59,000 dekatherms ("Dth") of the Partnership's gas
production maturing through September 2003 at a combined average price of $3.58
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 (loss) gain related to open NYMEX contracts was
$(52,700) and $17,900 at December 31, 2002 and 2001, respectively, which has
been recorded as an asset (liability) on the Partnership's Balance Sheet and in
partners' capital as accumulated other comprehensive income (loss). The
unrealized loss at December 31, 2002 is expected to be reclassified to earnings
during the next 12 months. The Partnership recognized losses of approximately
$14,600 and $76,300 on settled contracts covering natural gas production for the
years ended December 31, 2002 and 2001, respectively, which is included in
natural gas and oil sales.

        The Partnership recognized no gains or losses during the years ended
December 31, 2002 and 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 derivative's fair value.

NOTE 9 - 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". Annually, reserve value information is
provided to the limited partners pursuant to the partnership agreement. The
partnership agreement provides a presentment feature whereby the managing
general partner will buy partnership units, subject to annual limitations, based
upon a valuation formula price in the partnership agreement. Therefore, reserve
value information under SFAS No. 69 is not presented.

        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.




                                       23
<PAGE>



                 Atlas-Energy for the Nineties - Public #8 Ltd.
                      (A Pennsylvania Limited Partnership)
                         NOTES TO FINANCIAL STATEMENTS
                               December 31, 2002

NOTE 9 - NATURAL GAS AND OIL PRODUCING ACTIVITIES (Continued)

Capitalized Costs

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

<TABLE>
<CAPTION>
                                                             2002                2001
                                                        ---------------    -----------------
<S>                                                     <C>                <C>
Capitalized costs at December 31:
   Proved properties                                    $   12,573,800     $     12,573,800
   Accumulated depreciation and depletion                   (7,704,400)          (5,477,500)
                                                        ---------------    -----------------
            Net capitalized costs                       $    4,869,400     $      7,096,300
                                                        ===============    =================
</TABLE>

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 years ended December 31, 2002 and 2001:

<TABLE>
<CAPTION>
                                                              2002                    2001
                                                        ------------------      -----------------
<S>                                                     <C>                     <C>
Natural gas and oil sales                               $       1,172,800       $      2,517,000
Production costs                                                 (296,000)              (480,100)
Depreciation and depletion and impairment                      (2,226,900)            (4,486,800)
                                                        ------------------      -----------------
    Results of operations from oil and gas
        producing activities                            $      (1,350,100)      $     (2,449,900)
                                                        ==================      =================
</TABLE>

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.



                                       24
<PAGE>

                 Atlas-Energy for the Nineties - Public #8 Ltd.
                      (A Pennsylvania Limited Partnership)
                          NOTES TO FINANCIAL STATEMENTS
                               December 31, 2002

NOTE 9 - NATURAL GAS AND OIL PRODUCING ACTIVITIES (UNAUDITED) (Continued)


<TABLE>
<CAPTION>
                                                  Natural Gas             Oil
                                                    (MCF)               (BBLS)
                                                ---------------     --------------
<S>                                             <C>                 <C>
Balance, December 31, 2000                           8,148,900               1,700
     Production                                       (511,200)                 -
     Revisions to previous estimates                (4,469,600)                 -
                                                ---------------     --------------
Balance, December 31, 2001                           3,168,100               1,700
                                                     3,168,100
     Production                                       (343,000)               (200)
     Revisions to previous estimates                  (297,500)              1,000
                                                ---------------     --------------
 Balance, December 31, 2002                           2,527,600              2,500
                                                ===============     ==============
</TABLE>













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

        None.




                                       25
<PAGE>




                                    PART III

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 September 30, 2002, our
managing general partner and its affiliates had directly or through investments
in partnerships similar to our interest in approximately 5,000 gross wells,
including royalty or overriding interests in 600 wells. Our managing general
partner or its' affiliates operate 85% of these wells which are 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 proprietary asset management company who is engaged in the
energy, real estate and financial services sectors. 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.




                                       26
<PAGE>



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

NAME                        AGE      POSITION OR OFFICE
----                        ---      -------------------

Freddie M. Kotek            46       Chairman of the Board of Directors, Chief
                                       Executive Officer and President
Frank P. Carolas            42       Executive Vice President - Land and
                                       Geology and a Director
Jeffrey C. Simmons          43       Executive Vice President - Operations
                                      and a Director
Jack L. Hollander           46       Senior Vice President - Direct
                                      Participation Programs
Nancy J. McGurk             47       Senior Vice President, Chief
                                      Financial Officer and Chief
                                      Accounting Officer
Michael L. Staines          53       Senior Vice President, Secretary
                                      and a Director

With respect to the biographical information set forth below:

                  o        the approximate amount of an individual's
                           professional time devoted to the business and affairs
                           of the managing general partner and Atlas America
                           have been aggregated because there is no reasonable
                           method for them to distinguish their activities
                           between the two companies; and

                  o        for those individuals who also hold senior positions
                           with other affiliates of the managing general
                           partner, if it is stated that they devote
                           approximately 100% of their professional time to the
                           managing general partner and Atlas America, it is
                           because either the other affiliates are not currently
                           active in drilling new wells, such as Viking
                           Resources or Resource Energy, and the individuals are
                           not required to devote a material amount of their
                           professional time to the affiliates, or there is no
                           reasonable method to distinguish their activities
                           between the managing general partner and Atlas
                           America as compared with the other affiliates of the
                           managing general partner, such as Viking Resources or
                           Resource Energy.

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. Mr. Kotek received a Bachelor of Arts degree from
Rutgers College in 1977 with high honors in Economics. He also received a Master
in Business Administration degree from the Harvard Graduate School of Business
Administration in 1981. Mr. Kotek devotes approximately 80% of his professional
time to the business and affairs of the managing general partner and Atlas
America, and the remainder of his professional time to the business and affairs
of the managing general partner's affiliates.

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 and a Director since January, 2002.
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 Energy 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 Resources and its affiliates since 1981. He received a Bachelor of
Science degree in Geology from Pennsylvania State University in 1981 and is an
active member of the American Association of Petroleum Geologists. Mr. Carolas
devotes approximately 100% of his professional time to the business and affairs
of the managing general partner and Atlas America.



                                       27
<PAGE>

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 and a Director since January, 2002. 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 also serves as Vice President of Atlas Energy Corp., Atlas Energy Group,
Inc., PA Industrial Energy, Inc., Viking Resources, Corp., and Atlas Pipeline
Partners G.P., President of REI-NY, Inc. and Resource Well Services, Inc., and
Executive Vice President of Atlas Noble Corp. Mr. Simmons joined Resource
America in 1986 as senior petroleum engineer. From 1988 through 1994 he served
as director of production and as president of Resource Well Services, Inc., a
subsidiary of Resource America. He was then promoted to vice president of
Resource Energy, Inc., the energy subsidiary of Resource America formed in 1993.
In 1997 he was promoted to executive vice president, chief operating officer and
director of Resource Energy, Inc., a position he currently holds. Before Mr.
Simmons' career with Resource America, he had worked with Core Laboratories,
Inc., of Dallas, Texas, and PNC Bank of Pittsburgh. Mr. Simmons received his
Petroleum Engineering degree from Marietta College and his Masters degree in
Business Administration from Ashland University. He is a Board Member of the
Ohio Oil and Gas Association, the Independent Oil and Gas Association of New
York, and the Ohio Section of the Society of Petroleum Engineers. Mr. Simmons
devotes approximately 80% of his professional time to the business and affairs
of the managing general partner and Atlas America, and the remainder of his
professional time to the business and affairs of the managing general partner's
affiliates, primarily Viking Resources and Resource Energy.

Jack L. Hollander. Senior Vice President - Direct Participation Programs since
January, 2002. Mr. Hollander also serves as Senior Vice President - Direct
Participation Programs of Atlas America since January, 2002. Mr. Hollander
served as Vice President - Direct Participation Programs for the managing
general partner and Atlas America from 2001 until January, 2002. 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. Mr. Hollander earned a Bachelor of Science degree from
the University of Rhode Island in 1978, his law degree from Brooklyn Law School
in 1981, and a Master of Law degree in Taxation from New York University School
of Law Graduate Division in 1982. Mr. Hollander is a member of the New York
State bar, the Investment Program Association, and the Financial Planning
Association. Mr. Hollander devotes approximately 100% of his professional time
to the business and affairs of the managing general partner and Atlas America.






                                       28
<PAGE>


Nancy J. McGurk. Senior Vice President, Chief Financial Officer and Chief
Accounting Officer since January, 2002. Ms. McGurk also serves as Senior Vice
President, Chief Financial Officer, and Chief Accounting Officer of Atlas
America since January, 2002. Ms. McGurk served as Vice President, Chief
Financial Officer and Chief Accounting Officer of the managing general partner
and Atlas America from January, 2001 to January, 2002. Ms. McGurk has been Vice
President of Resource America since 1992 and 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,
Inc. Ms. McGurk devotes approximately 20% of her professional time to the
business and affairs of the managing general partner and Atlas America, and the
remainder of her professional time to the business and affairs of the managing
general partner's affiliates.

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,
Inc., 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. Mr. Staines is a member of the Ohio Oil and Gas Association and the
Independent Oil and Gas Association of New York. Mr. Staines received a Bachelor
of Science degree from Cornell University in 1971 and a Master of Business
degree from Drexel University in 1977. Mr. Staines devotes approximately 10% of
his professional time to the business and affairs of the managing general
partner and Atlas America, and the remainder of his professional time to the
business and affairs of the managing general partner's affiliates.


ITEM 10.  EXECUTIVE COMPENSATION

         We have no employees and rely on the employees of our managing general
partner and its affiliates for all services. We did not directly pay any
compensation to the employees of our managing general partner since inception
nor do we expect to do so in future years. 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, 2002, we had issued and outstanding 1,111 units. No
officer or director of our managing general partner owns any units. Although,
subject to certain conditions, investor partners may present their units to us
beginning in 2004 for purchase. However, we are not obligated to purchase more
than 5% of the units in any colander year.

         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.




                                       29
<PAGE>


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 years ended December 31, 2002 and 2001, our managing general partner
received $254,300 and $590,700, 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 2002 and 2001, 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 years ended
December 31, 2002 and 2001, our managing general partner received $47,500 and
$52,700, 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 ended December 31, 2002 and 2001, our managing general partner received
$141,300 and $176,700, 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 2002 and 2001, we did not enter into any further drilling transactions
and none are anticipated for future periods.

       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 years ended December 31, 2002 and
2001, our managing general partner received $144,200 and $157,300, respectively,
for well supervision fees.

       Gathering Fees. We pay a gathering fee at a competitive rate for each mcf
transported through Atlas Pipeline Partners, L.P., natural gas gathering system,
currently ranging $.29-$.35 per mcf. For the years ended December 31, 2002 and
2001 these amounts were $67,500 and $146,100, respectively.

       Other Compensation. For the years ended December 31, 2002 and 2001, 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 32.



                                       30
<PAGE>


ITEM 14.  CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

         Our Chief Executive Officer and Chief Financial Officer have evaluated
 our disclosure controls and procedures, (as defined in Rules 13a-14 (c) and
 15d-14(c)) within 90 days prior to the filing of this report. Based upon this
 evaluation, these officers believe that our disclosure controls and procedures
 are effective.

Changes in Internal Controls

         There were no significant changes in our internal controls or in other
factors that could significantly affect these controls subsequent to the date of
our last evaluation of our internal controls by our Chief Executive Officer and
Chief Financial Officer.



                                       31
<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 ended
                                                                       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 ended
           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 ended
                                                                       December 31, 1999
</TABLE>


99.1     Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant
         to Section 906 of The Sarbanes-Oxley Act of 2002


99.2     Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant
         to Section 906 of The Sarbanes-Oxley Act of 2002




                                       32
<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.


Atlas-Energy for the Nineties Public #8 Ltd.

By:  (Signature and Title):
                                   -------------------------------------------
                                   Atlas Resources, Inc., Managing General
                                   Partner

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

Date: March 28, 2003


        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):         /s/ Freddie M. Kotek
                                   -------------------------------------------
                                   Freddie M. Kotek,  Chairman of the Board
                                   of Directors,  Chief Executive Officer
                                   and President

Date: March 28, 2003


By  (Signature and Title):          /s/ Frank P. Carolas
                                    -------------------------------------------
                                    Frank P. Carolas, Executive Vice
                                    President-Land and Geology and a Director
Date: March 28, 2003


By  (Signature and Title):          /s/ Jeffrey C. Simmons
                                    -------------------------------------------
                                    Jeffrey C. Simmons, Executive Vice
                                    President-Operations and a Director
Date: March 28, 2003

By  (Signature and Title):          /s/ Nancy J. McGurk
                                    -------------------------------------------
                                    Nancy J. McGurk,  Vice President,  Chief
                                    Financial Officer and Chief Accounting
                                    Officer
Date: March 28, 2003


                    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.





                                       33
<PAGE>

                                 CERTIFICATIONS

I, Freddie M. Kotek, Chief Executive Officer of Atlas Resources, Inc. (managing
general partner of the Partnership), hereby certify that:

1.       I have reviewed this annual report on Form 10-KSB of Atlas-Energy for
         the Nineties-Public #8 Ltd;

2.       Based on my knowledge, this annual report does not contain any untrue
         statement of a material fact or omit to state a material fact necessary
         to make the statements made, in light of the circumstances under which
         such statements were made, not misleading with respect to the period
         covered by this annual report;

3.      Based on my knowledge, the financial statements, and other financial
        information included in this annual report, fairly present in all
        material respects the financial condition, results of operations and
        cash flows of the registrant as of, and for, the periods presented in
        this annual report;

4.      The registrant's other certifying officer and I are responsible for
        establishing and maintaining disclosure controls and procedures (as
        defined in Exchange Act Rules 13a-14 and 15d-14) for the registrant and
        we have:

         a)       designed such disclosure controls and procedures to ensure
                  that material information relating to the registrant,
                  including its consolidated subsidiaries, is made known to us
                  by others within those entities, particularly during the
                  period in which this annual report is being prepared;

         b)       evaluated the effectiveness of the registrant's disclosure
                  controls and procedures as of a date within 90 days prior to
                  the filing date of this annual report (the "Evaluation Date");
                  and

         c)       presented in this annual report our conclusions about the
                  effectiveness of the disclosure controls and procedures based
                  on our evaluation as of the Evaluation Date;

5.      The registrant's other certifying officer and I have disclosed, based on
        our most recent evaluation, to the registrant's auditors and the audit
        committee of registrant's board of directors (or persons performing the
        equivalent function):

         a)       all significant deficiencies in the design or operation of
                  internal controls which could adversely affect the
                  registrant's ability to record, process, summarize and report
                  financial data and have identified for the registrant's
                  auditors any material weaknesses in internal controls; and

         b)       any fraud, whether or not material, that involves management
                  or other employees who have a significant role in the
                  registrant's internal controls; and

6.      The registrant's other certifying officer and I have indicated in this
        annual report whether or not there were significant changes in internal
        controls or in other factors that could significantly affect internal
        controls subsequent to the date of our most recent evaluation, including
        any corrective actions with regard to significant deficiencies and
        material weaknesses.

                    By: /s/ Freddie M. Kotek
                    ------------------
                    Freddie M. Kotek
                    Chief Executive Officer of the Managing General Partner
                    March 28, 2003




                                       34
<PAGE>





                                 CERTIFICATIONS

I, Nancy J. McGurk, Chief Financial Officer of Atlas Resources, Inc. (managing
general partner of the Partnership), hereby certify that:

1.       I have reviewed this annual report on Form 10-KSB of Atlas-Energy for
         the Nineties-Public #8 Ltd;

2.       Based on my knowledge, this annual report does not contain any untrue
         statement of a material fact or omit to state a material fact necessary
         to make the statements made, in light of the circumstances under which
         such statements were made, not misleading with respect to the period
         covered by this annual report;

3.       Based on my knowledge, the financial statements, and other financial
         information included in this annual report, fairly present in all
         material respects the financial condition, results of operations and
         cash flows of the registrant as of, and for, the periods presented in
         this annual report;

4.       The registrant's other certifying officer and I are responsible for
         establishing and maintaining disclosure controls and procedures (as
         defined in Exchange Act Rules 13a-14 and 15d-14) for the registrant and
         we have:

         a)       designed such disclosure controls and procedures to ensure
                  that material information relating to the registrant,
                  including its consolidated subsidiaries, is made known to us
                  by others within those entities, particularly during the
                  period in which this annual report is being prepared;

         b)       evaluated the effectiveness of the registrant's disclosure
                  controls and procedures as of a date within 90 days prior to
                  the filing date of this annual report (the "Evaluation Date");
                  and

         c)       presented in this annual report our conclusions about the
                  effectiveness of the disclosure controls and procedures based
                  on our evaluation as of the Evaluation Date;

5.       The registrant's other certifying officer and I have disclosed, based
         on our most recent evaluation, to the registrant's auditors and the
         audit committee of registrant's board of directors (or persons
         performing the equivalent function):

         a)       all significant deficiencies in the design or operation of
                  internal controls which could adversely affect the
                  registrant's ability to record, process, summarize and report
                  financial data and have identified for the registrant's
                  auditors any material weaknesses in internal controls; and

         b)       any fraud, whether or not material, that involves management
                  or other employees who have a significant role in the
                  registrant's internal controls; and

6.      The registrant's other certifying officer and I have indicated in this
        annual report whether or not there were significant changes in internal
        controls or in other factors that could significantly affect internal
        controls subsequent to the date of our most recent evaluation, including
        any corrective actions with regard to significant deficiencies and
        material weaknesses.

                    By: /s/ Nancy J. McGurk
                    ------------------
                    Nancy J. McGurk
                    Chief Financial Officer of the Managing General Partner
                    March 28, 2003




                                       35