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
THESECURITIES EXCHANGE ACT OF 1934

For the year ended December 31, 2003

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

For the transition period
from _______ to _______

Commission file number
333-44130

Atlas America Public #9 Ltd.
(Name of small business issuer in its charter)

Pennsylvania      
                   
                   
                   
                   
                   
                   
                   
           25-1867510(State or other jurisdiction of   
                   
                   
                   
                   
                   
                   
(I.R.S. Employerincorporation or organization)              
                   
                   
                   
                   
                   
      Identification No.)



311 Rouser RoadMoon 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. YesXNo

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. $3,089,300

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):
        YesNoX

---

ATLAS AMERICA PUBLIC #9 LTD.(A Pennsylvania Limited Partnership)INDEX TO ANNUAL REPORT
ON FORM 10-KSB

|               |  |                                                                    
|-------------- |  | -------------------------------------------------------------------
|PART I         |  |                                                                    
|              
|Item 1:        |  | Business                                                           
|Item 2:        |  | Properties                                                         
|Item 3:        |  | Legal Proceedings                                                  
|Item 4:        |  | Submission of Matters
         to a Vote of Security Holders       
|              
|PART II        |  |                                                                    
|              
|Item 5:        |  | Market for Registrant's
         Common Equity and Related Security
|               |  | Holder
         Matters                                            
|Item 6:        |  | Management's Discussion and
         Analysis of                   
|               |  | Condition
         and Results of Operations                       
|Item 7:        |  | Financial Statements                                               
|Item 8:        |  | Changes in and Disagreements
         with Accountants on          
|               |  | Accounting
         and Financial Disclosure                       
|Item 8A:       |  | Controls and Procedures                                            
|              
|PART III       |  |                                                                    
|Item 9:        |  | Directors, Executive Officers
         and Significant Employees,  
|               |  | Compliance
         with Section (16b) of the Exchange Act         
|Item 10:       |  | Executive Compensation                                             
|Item 11:       |  | Security Ownership of
         Certain Beneficial Owners and       
|               |  | Management                                                         
|Item 12:       |  | Certain Relationships
         and Related Transactions            
|Item 13:       |  | Exhibits and Reports
         on Form 8-K                          
|Item 14:       |  | Principal Accountant Fees and
         Services                    
|              
|SIGNATURES     |  |                                                                    
|              
|CERTIFICATIONS |  |                                                                    

---

PART I

ITEM 1.      
 DESCRIPTION OF BUSINESS

General.
   We were formed as a Pennsylvania limited partnership on July 27, 2000, 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(b) of the Exchange Act.

We
began our drilling activities upon our initial closing date of December 1, 2000 and our
final closing date was December 31, 2000. We received total cash subscriptions from
investors of $14,905,500 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 and paid all organization and offering  costs and 100%
of the tangible costs for a total capital contribution to
us of $6,256,300. We drilled and completed a total of 78.75 net developmental 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, delivery and sale of gas and to a lesser extent oil, such as:

   
       well
tending, routine maintenance and adjustment;

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

   
       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
our estimated future plugging and abandonment costs. As of December 31, 2003 the managing
general partner has not withheld such funds.

---

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 2003 and 2002,
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:

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

     
      minimum well spacing requirements;

     
      restrictions on well locations and underground gas storage;

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

     
      landowner notification requirements;

     
      certain bonding or other security measures;

     
      various reporting requirements;

     
      well plugging standards and procedures; and

     
      broad enforcement powers.

---

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. 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 10-KSB Annual Report and Form 10-QSB 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 America Public #9
Ltd.

311 Rouser Road

Moon Township, PA 15108

ITEM 2.   PROPERTIES

Drilling Activity.    For the year ended December 31, 2003 and 2002, 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, 2003 in which we have a working interest. All of our wells
are classified as gas wells.

| | Number of Productive Wells
| | --------------------------
|
| | Pennsylvania              
| | Ohio                      
| | Total                     

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

| | Production | Average Sales Price | Average
| | ---------- | ------------------- | -------
|
|
|
| | 2003       |                     | 3,900  
| | 2002       |                     | 4,400  

__________________________________

|(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. 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 year-end weighted average prices:

|                      | As of December 31,
|--------------------- | ------------------
|
|Natural gas (per mcf) |                   
|Oil (per bbl)         |                   

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 our reports. 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 we used in preparing our reports. The
amounts and timing of future operating, development and abandonment 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.

---

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.

|                                                                 | As of December 31,
|---------------------------------------------------------------- | ------------------
|
|                                                                
|Natural gas reserves -
         Proved Reserves (Mcf)(1)(5):     |                   
|Proved developed
         reserves (2)                           |                   
|Proved undeveloped
         reserves (3)                         |                   
|Total
         proved reserves of natural gas                    |                   
|                                                                
|Oil reserves: - Proved Reserves
        (Bbl)(1)(5)              |                   
|Proved developed
         reserves (2)                           |                   
|Proved undeveloped
         reserves (3)                         |                   
|Total
         proved reserves of oil                            |                   
|                                                                
|Total proved reserves (Mcfe)                                     |                   
|                                                                
|PV-10 estimate of cash flows of
         proved reserves (4)(5): |                   
|Proved developed
         reserves                               |                   
|Proved undeveloped
         reserves                             |                   
|Total
        PV-10 estimate                                     |                   
|                                                                



|(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.
|--- |  | -------------------------------------------------------------------------------------------------------------------------------------------------

|(5) |  | Please see Regulation S-X rule 4-10 for complete definitions of each reserve category.
|--- |  | --------------------------------------------------------------------------------------

---

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, 2003.

|             | Developed Acreage | Undeveloped Acreage (3)
|------------ | ----------------- | -----------------------
|
|Pennsylvania |                   | 1,963                  
|Ohio         |                   | 911                    
|Total        |                   | 2,874                  



|(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.  Our managing
general partner, Resource Energy, Inc. and Atlas Energy Group, Inc, both of which are affiliates of our
managing general partner, have a natural gas supply agreement with First Energy Solutions
Corporation for a 10-year term, which began on April 1, 1999. Substantially all of our gas
is sold through this agreement. Subject to certain exceptions, First Energy Solutions
Corporation has a last right of refusal to buy all of the natural gas produced and
delivered by the managing general partner, its affiliates and partnerships at certain
delivery points with the facilities of East Ohio Gas Company, National Fuel Gas
Distribution, Columbia of Ohio, 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.

First Energy Solutions Corporation is
the marketing affiliate of First Energy Corporation, which is based in Akron, Ohio and is
a large regional electric utility listed on the New York Stock Exchange and trading under
the symbol (FE). First Energy Corporation has provided a guaranty of the monetary
obligations of First Energy Solutions Corporation of an amount up to $15 million for a
period until March 31, 2005, which will continue on a monthly basis thereafter unless
terminated on 30 days notice. As of January 1, 2004, this guaranty would cover natural gas
sales of all the managing general partners partnerships for approximately 85 days of
sales.

The pricing arrangements with First
Energy Solutions Corporation and other third parties are tied to the New York Mercantile
Exchange Commission (NYMEX) monthly futures contract price, which is reported
daily in the Wall Street Journal. The total price received for each partnerships gas
is a combination of the monthly NYMEX futures price plus a fixed basis. For example, the
NYMEX futures price is the base price and there is an additional premium paid because of
the location of the gas (the Appalachian Basin) in relation to the gas market which is
referred to as the basis. The premium over quoted prices on the NYMEX received by the
managing general partner and its affiliates has ranged between $0.33 to $0.46 per Mcf
during the past three fiscal years. The agreement with First Energy Solutions Corporation
may be suspended for force majeure, which means generally such things as an act of God,
fire, storm, flood, and explosion, but also includes the permanent closing of the
factories of Carbide Graphite or Duferco Farrell Corporation during the term of First
Energy Solutions Corporations agreements to sell natural gas to them. If these
factories were closed, however, the managing general partner believes that First Energy
Solutions Corporation would be able to find alternative purchasers and would not invoke
the force majeure.

Pricing for natural gas and oil has
been volatile and unpredictable for many years. The agreement with First Energy Solutions
Corporation also permits the managing general partner and its affiliates to implement gas
price hedges through First Energy Solutions Corporation. First Energy Solutions
Corporation and the other third-party marketers also use NYMEX based financial instruments
to hedge their pricing exposure and make price-hedging opportunities available to the
managing general partner. The majority of the managing general partners hedges are
implemented through its natural gas purchasers. These transactions are similar to NYMEX
based futures contracts, swaps and options, but also require firm delivery of the hedged
quantity. Thus, the 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 and any other third-party marketers for certain volumes
of natural gas sold under these hedge agreements may be significantly different from the
underlying monthly spot market value. Additionally, to limit the managing general
partners and its partnerships exposure to changes in natural gas prices the
managing general partner uses hedges through contracts including regulated NYMEX futures
and options contracts and non-regulated over-the-counter futures contracts with qualified
counterparties. The futures contracts employed by the managing general partner are
commitments to purchase or sell natural gas at future dates and generally cover one-month
periods for up to 24 months in the future. The overall portion of our natural gas
portfolio that is hedged changes from time to time.

To
assure that all financial instruments will be used solely for hedging price risks and not
for speculative purposes, the managing general partner has established a committee to
assure that all gas prices hedges, either those through a third party marketer or through
contracts are done in compliance with the managing general partners hedging policies
and procedures. The managing general partner does not intend to contract for positions
that it cannot offset with actual production.

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,
For the next twelve months, our managing general partner anticipates that approximately
75% of our natural gas will be sold to First Energy Solutions Corporation and the balance
to the other markets.

ITEM 3.   LEGAL
PROCEEDINGS

None.

ITEM 4.   SUBMISSION
OF MATTERS TO A VOTE OF SECURITIES HOLDERS

None.

---

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:

    
 our managing general partner consent;

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

    
 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:

     
the assignor gives the assignee the right;

     
our managing general partner consents to the substitution;

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

     
the assignee executes and delivers the instruments which our managing general partner requires to
effect thesubstitution 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, 2003, we had 533 interest holders.

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

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

During
the years ended December 31, 2003 and 2002 respectively, we distributed the following:

$1,663,800 and $2,551,700 our limited partners; and

$679,600 and $1,042,200 to our managing general partner.

---

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

Forward-Looking Statements.   When used
in this Form 10-KSB, 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:

|                                                 | Years Ended
|------------------------------------------------ | -----------
|
|
|Revenues (in thousands):                         |            
|Gas(1)(2)                                        |            
|Oil                                              |            
|Production volumes:                              |            
|Gas
         (thousands of cubic feet (mcf)/day) |            
|Oil
         (barrels (bbls)/day)                |            
|Average sales price:                             |            
|Gas
        (per mcf)                            |            
|Oil
         (per bbl)                           |            
|Production costs:                                |            
|As a
         percent of sales                   |            
|Per
        equivalent mcf                       |            



(1) Excludes sales of residual gas and
sales to landowners.(2) The average sales price per (mcf)
before the effects of hedging was $5.21 and $3.70 for the years ended December, 2003 and 2002, respectively.

Revenues.   Our production revenues for the year ended December 31, 2003
          were $3,087,600 a
          decrease of $353,300 (10%) from $3,440,900 for the year ended December 31,
          2002. The decrease was substantially due to a decrease of 817 mcf (33%) in
          our average daily natural gas production volumes. The decrease of $353,300 consisted of $723,400
          attributable to an increase in natural gas prices offset by $1,090,100 attributable to
          natural gas production volume decreases.  The remaining $13,400 increase was
          substantially due to a 28% increase in oil prices received.

The
price we receive for our natural gas is primarily a result of the index driven agreement
with First Energy Services Corporation (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.

---

Expenses.   Production expenses for the year ended December 31, 2003 were $553,900 compared
          to $651,100 for the year ended December 31, 2002, a decrease of $97,200 (15%).
          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, 2003 compared to the same period ended 2002.

Depletion
and depreciation of oil and gas properties as a percentage of oil and gas revenues was 44%
for the year ended December 31, 2003 compared to 72% for the year ended December 31, 2002.
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 $2,104,700. 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.  This is a non-recurring charge and is dependent on estimates
of reserve quantities, future market values and our carrying value.  We can not provide any assurance that similar
charges may or may not be taken in future periods.  For the year ended December 31, 2003 we had no such charge.

General
and Administrative expenses for the year ended December 31, 2003 amounted to $93,500
compared to $124,200 for the year ended December 31, 2002, a decrease of $30,700 (25%) mostly due to lower
charges incurred for certain outside services.

Liquidity and Capital Resources.   Cash provided by operating activities decreased
$1,268,700 most of which was due to changes in our operating assets and liabilities mainly due to a lesser
decrease in accounts receivable - affiliates because of lower amounts due from the sale of natural gas.

Cash
used by financing activities decreased $1,250,500 to $2,434,400 for the year ended
December 31, 2003 compared to the year ended December 31, 2002. The decrease is directly
related to a decrease in distributions to partners as a result of, the reduction in cash provided from operating
activities.

We had no new material commitments for us 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.

Recently
issued Financial Accounting Standards.   In April 2003, the Financial Accounting
Standards Board ("FASB") issued SFAS No. 149
("SFAS 149") "Amendment of Statement 133 on Derivative Instruments and Hedging Activates."  SFAS 149 is
effective for contracts entered into or modified after June 30, 2003 and amends and clarifies financial
accounting and reporting for derivative instruments.  The adoption of SFAS 149 did not have a
material effect on its financial position or results of operations.

In May 2003,
the FASB issued Statement No. 150 ("SFAS 150") "Accounting for Certain Financial Instruments with Characteristics
of Both Liabilities and Equity."  SFAS 150 requires that certain instruments that were previously classified
as equity on a Partnership's statement of financial position now be classified as liabilities.  SFAS 150 is
effective for financial instruments entered into or modified after May 31, 2003, and otherwise is effective
at the beginning of the first interim period beginning after June 15, 2003.  The adoption of SFAS 150 did not
have an impact on the Partnership's results of operations or financial position.

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, abandonment costs, 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.

Classification of mineral rights.  Oil and gas properties include mineral rights
with an estimated cost of $264,200.  The provisions of Statement of Financial Accounting Standards No. 141 ("SFAS 141") "Business
Combinations", suggest that mineral rights may, in fact, be more appropriately classified as intangible assets.

The staff of the Securities and Exchange Commission has made the Partnership aware that an issue
has arisen within the industry regarding the application of provisions of SFAS No. 142 "Goodwill and Intangible
Assets" and SFAS No. 141 to entities in extractive industries, including gas and oil limited partnerships.
The issue is whether SFAS No. 142 requires entities to reclassify costs associated with mineral rights, including
both proved and unproved leasehold acquisition costs, as intangible assets on the balance sheet, apart from
other capitalized gas and oil property costs.  The Partnership has included the cost of these oil and gas leasehold
interests as part of oil and gas properties.  Also under consideration is whether SFAS No. 142 requires
companies to provide the additional disclosures prescribed by SFAS No. 142 for intangible assets for costs
associated with mineral rights.

If it is ultimately determined that SFAS No. 142 requires the Partnership to reclassify costs
associated with mineral rights from property and equipment to intangible assets, the reclassification of these amounts would not affect the method in which such
costs are amortized or the manner in which the Partnership assesses impairment of capitalized costs.  As a
result, net income and cash flow would not be affected by the reclassification.

---

ITEM 7.    
FINANCIAL STATEMENTS

REPORT OF INDEPENDENT
CERTIFIED PUBLIC ACCOUNTANTS

To the PartnersAtlas America
Public #9 Ltd.A Pennsylvania Limited Partnership

We have audited the accompanying
balance sheets of Atlas America Public #9 Ltd., A Pennsylvania Limited Partnership, as of
December 31, 2003 and 2002, and the related statements of operations, changes in
partners capital accounts and cash flows for 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 America Public #9 Ltd. as of December 31, 2003 and 2002 and the results
of its operations and cash flows for the years then ended, in conformity with accounting
principles generally accepted in the United States of America.

As discussed in Note 2 to the
financial statements, effective January 1, 2003 the Partnership adopted
Statement of Financial Accounting Standards No. 143, Accounting for Asset Retirement
Obligations,and changed its method of accounting for its plugging and abandonment
liability related to its oil and gas wells and associated equipment.

Cleveland, OhioFebruary 26, 2004

---

ATLAS AMERICA PUBLIC #9
LTD.(A Pennsylvania Limited Partnership)

BALANCE SHEETS
DECEMBER 31, 2003 AND 2002

|                                                       | 2003 | 2002
|------------------------------------------------------ | ---- | ----
|ASSETS                                                 |      |     
|Current assets:                                        |      |     
|Cash                                                   |      |     
|Accounts receivable - affiliate                        |      |     
|Total current assets                                   |      |     
|                                                       |      |     
|Oil and gas properties (successful
         efforts)   |      |     
|Less accumulated depletion and
         depreciation   |      |     
|                                                       |      |     
|                                                       |      |     
|                                                       |      |     
|                                                       |      |     
|LIABILITIES AND PARTNERS' CAPITAL                      |      |     
|Current liabilities:                                   |      |     
|Accrued liabilities                                    |      |     
|Unrealized hedging losses                              |      |     
|Total current liabilities                              |      |     
|                                                      
|Asset retirement obligation                            |      |     
|                                                       |      |     
|Partners' capital:                                     |      |     
|Managing general
         partner                      |      |     
|Limited partners
         (1,500 units)                |      |     
|Accumulated
         other comprehensive income (loss) |      |     
|                                                       |      |     
|                                                       |      |     

The
accompanying notes are an integral part of these financial statements

---

ATLAS AMERICA PUBLIC #9
LTD.
(A Pennsylvania Limited Partnership)

STATEMENTS OF OPERATIONS
YEARS ENDED DECEMBER 31, 2003 AND 2002

|                                                                                        | 2003 | 2002
|--------------------------------------------------------------------------------------- | ---- | ----
|REVENUES                                                                                |      |     
|Natural gas and oil sales                                                               |      |     
|Interest income                                                                         |      |     
|Total revenues                                                                          |      |     
|                                                                                        |      |     
|COSTS AND EXPENSES                                                                      |      |     
|Production expenses                                                                     |      |     
|Accretion of asset retirement obligation                                                |      |     
|Depletion and depreciation of oil
         and gas properties                           |      |     
|Impairment of oil and gas properties                                                    |      |     
|General and administrative
         expenses                                            |      |     
|Total expenses                                                                          |      |     
|                                                                                        |      |     
|Net earnings (loss) before cumulative effect
         of change in accounting principle |      |     
|                                                                                        |      |     
|Cumulative effect of change in accounting
         principle                            |      |     
|Net earnings (loss)                                                                     |      |     
|                                                                                        |      |     
|Allocation of net earnings (loss)                                                       |      |     
|                                                                                        |      |     
|Managing general
         partner                                                       |      |     
|                                                                                        |      |     
|Limited
         partners                                                               |      |     
|                                                                                        |      |     
|Net earnings (loss)
         before cumulative effect of change                         |      |     
|in accounting principle per limited partnership unit                                    |      |     
|Net earnings (loss)
         per limited partnership unit                               |      |     

The
accompanying notes are an integral part of these financial statements

---

ATLAS AMERICA PUBLIC #9
LTD.
(A Pennsylvania Limited Partnership)

STATEMENTS OF CHANGES IN PARTNERS' CAPITAL ACCOUNTS
YEARS ENDED DECEMBER 31, 2003 AND 2002

|                                                          |  |  | Accumulated |           
|--------------------------------------------------------- |  |  | ----------- | ----------
|
|
|
|Balance at December 31, 2001                              |  |  | $           | 5,393,700 
|                                                          |  | 
|Comprehensive income (loss):                              |  | 
|Participation in
         revenue and expenses:           |  | 
|Net
         production revenues                          |  |  |             | 824,800   
|Interest income                                           |  |  |             | 1,200     
|Depletion and depreciation                                |  |  |             | (721,000  
|Impairment of oil and gas properties                      |  |  |             | (609,600  
|General and administrative                                |  |  |             | (36,700   
|                                                          |  | 
|Net loss                                                  |  |  |             | (541,300  
|Cash flow hedge losses reclassified
         to gas sales |  |  |             | -         
|Change in fair value of cash
         flow hedges         |  |  |             | -         
|Comprehensive loss                                        |  |  |             |           
|Distributions to partners                                 |  |  |             | (1,042,200
|                                                          |  | 
|Balance at December 31, 2002                              |  |  | $           | 3,810,200 
|                                                          |  | 
|Comprehensive income (loss):                              |  | 
|Participation in
         revenue and expenses:           |  | 
|Net production revenues                                   |  |  |             | 749,100   
|Interest income                                           |  |  |             | 500       
|Depletion and depreciation                                |  |  |             | (416,100  
|Accretion of asset retirement obligations                 |  |  |             | (7,100    
|General and administrative                                |  |  |             | (27,600   
|                                                          |  | 
|Net earnings before cumulative effect                     |  |  |             | 298,800   
|of change in accounting principle                         |  | 
|                                                          |  | 
|                                                          |  | 
|Cumulative effect of
         change in accounting        |  |  |             | (117,600  
|principle                                                 |  | 
|                                                          |  | 
|Net earnings                                              |  |  |             | 181,200   
|Change in fair value of cash flow hedges                  |  |  |             | -         
|Cash flow hedge losses reclassified
         to gas sales |  |  |             | -         
|Comprehensive income                                      |  |  |             |           
|Distributions to partners                                 |  |  |             | (679,600  
|                                                          |  | 
|Balance at December 31, 2003                              |  |  | $           | 3,311,800 

The accompanying
notes are an integral part of these financial statements

---

ATLAS AMERICA PUBLIC #9
LTD.
(A Pennsylvania Limited Partnership)

STATEMENTS OF CASH FLOWS
YEARS ENDED DECEMBER 31, 2003 AND 2002

|                                                                           | 2003 | 2002
|-------------------------------------------------------------------------- | ---- | ----
|Cash flows from operating
         activities:                             |      |     
|Net earnings (loss)                                                        |      |     
|Adjustments to reconcile net earnings
         (loss) to net cash provided |      |     
|by operating
         activities:                                          |      |     
|Impairment
         of oil and gas properties                              |      |     
|Accretion
         of asset retirement obligations                         |      |     
|Cumulative
         effect of change in accounting principle               |      |     
|Depletion
         and depreciation                                        |      |     
|Decrease in accounts receivable - affiliate                                |      |     
|(Decrease)
         increase in accrued liabilities                        |      |     
|                                                                          
|Net cash provided by operating activities:                                 |      |     
|                                                                          
|Cash flows from financing activities:                                      |      |     
|                                                                          
|Capital distributions                                                      |      |     
|                                                                          
|Net cash used in financing activities                                      |      |     
|                                                                          
|Net increase in cash                                                       |      |     
|                                                                          
|Cash at beginning of year                                                  |      |     
|                                                                          
|Cash at end of year                                                        |      |     

The
accompanying notes are an integral part of these financial statements

---

Atlas America Public #9
Ltd.
(A Pennsylvania Limited Partnership)

NOTES TO FINANCIAL
STATEMENTS
December 31, 2003

NOTE 1  NATURE OF
OPERATIONS

Atlas
America Public #9 Ltd. (the Partnership) is a Pennsylvania Limited Partnership
which includes Atlas Resources, Inc. (Atlas) of Pittsburgh, Pennsylvania, as
Managing General Partner and Operator, and 533 Limited Partners. The Partnership was
formed on July 27, 2000 to drill and operate gas wells located primarily in western
Pennsylvania. At December 31, 2003, the Partnership had various working interests in 83
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.

Reclassifications

Certain reclassifications have
been made to the fiscal 2002 financial statements to conform to the 2003 presentation.

Use of Estimates

Preparation of the
financial statements in conformity with accounting principles generally accepted in the United States of America
requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities
and the disclosure of contingent assets and liabilities as of the date of the financial statements
and the reported amounts of revenues and costs and expenses during the reporting period.  Actual results could differ
from these estimates.

Impairment of Long Lived Assets

The Partnership reviews its
long-lived assets for impairment whenever events or circumstances indicate that the carrying amount of an asset
may not be recoverable.  If it is determined that an asset's estimated future cash flows will not be sufficient
to recover its carrying amount, an impairment charge will be recorded to reduce the carrying amount for that asset
to its estimated fair value.

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 only include changes in the unrealized hedging gains and losses.

Oil and Gas Properties

Oil and gas
properties consists of the following:

|                                                                                     | At December 30,
|------------------------------------------------------------------------------------ | ---------------
|
|Mineral interest in properties:                                                      |                
|Proved properties                                                                    |                
|Wells and related equipment                                                          |                
|                                                                                     |                
|Accumulated depreciation, depletion,
         amortization and valuation allowances: |                
|Oil and gas
         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.  Costs of exploratory
wells which do not find proved reserves are expensed.  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.

---

# AtlasAmerica Public #9 Ltd.(A Pennsylvania Limited Partnership)

# NOTES TO FINANCIAL
STATEMENTS

December 31, 2003

# NOTE 2  SUMMARY OF
SIGNIFICANT ACCOUNTING POLICIES (Continued)

Oil and Gas Properties - (Continued)

Oil and gas
properties include mineral rights with a cost at December 31, 2003 of $264,200 before accumulated depletion.
The Partnership became aware that an issue has arisen within the industry regarding the application of the
provisions of Statement of Financial Accounting Standards ("SFAS") No. 142,"Goodwill and Other Intangible
Assets" and SFAS No. 141, "Business Combinations," to entities in the extractive industries, including gas
and oil partnerships.  The issue is whether SFAS No. 142 requires entities to reclassify costs associated
with mineral rights, including both proved and unproved leasehold acquisition costs, as intangible assets
in the balance sheet, apart from other capitalized gas and oil property costs.  Historically, the Partnership
and other gas and oil companies and partnerships have included the cost of these leasehold interests as part
of gas and oil properties.  Also under consideration is whether SFAS No. 142 requires entities to provide
the additional disclosures prescribed by SFAS No. 142 for intangible assets for costs associated with
mineral rights.

If it is ultimately
determined that SFAS No. 142 requires the Partnership to reclassify costs associated with mineral rights from
property and equipment to intangible assets, the reclassification of these amounts would not affect the method in which such costs are amortized
or the manner in which the Partnership assesses impairment of capitalized costs.  As a result, net income
would not be affected by the reclassification.

The
Partnership assesses proved properties periodically to determine whether there has been a decline in value and,
if a decline is indicated, a loss is recognized.  The Partnership compares the carrying value of its proved
developed gas and oil producing properties to the estimated future cash flow from such properties in order
to determine whether their carrying values should be reduced.  As a result of this assessment, an impairment
loss of $2,104,700 was recognized in fiscal year 2002.  No impairment loss was required in fiscal year 2003.

Upon the sale or
retirement of a complete or partial unit of a proved property, the cost and related accumulated depletion are eliminated
from the property accounts, and the resultant gain or loss is recognized in the statement of operations.

On an annual 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, the Partnership's estimate of equipment
salvage values was greater than or equal to the estimated costs of future dismantlement, restoration,
reclamation, and abandonment.  On January 1, 2003, the Partnership adopted SFAS No. 143 "Accounting for
Asset Retirement Obligations" ("SFAS 143") as discussed further in this footnote.

Depreciation, Depletion and Amortization

The Partnership
amortizes proved gas and oil properties, which include intangible drilling and development costs, tangible well
equipment and leasehold costs, on the unit-of-production method using the ratio of current production to the estimated
aggregate proved developed gas and oil reserves.

---

# Atlas America Public #9 Ltd.(A Pennsylvania Limited Partnership)

# NOTES TO FINANCIAL
STATEMENTS

December 31, 2003

# NOTE 2  SUMMARY OF
SIGNIFICANT ACCOUNTING POLICIES (Continued)

Asset Retirement Obligations

Effective January 1, 2003
the Partnership adopted SFAS 143 which requires the Partnership to recognize an estimated liability for the plugging and
abandonment of its oil and gas wells.  Under SFAS 143, the Partnership must
currently recognize a liability for future asset retirement obligations if a reasonable estimate of the fair value
of that liability can be made.  The present values of the expected asset retirement costs are capitalized as part of the
carrying amount of the long-lived asset.  SFAS 143 requires the Partnership to consider estimated salvage
value in the calculation of depletion, depreciation and amortization.  Consistent with industry practice,
historically the Partnership had determined the cost of plugging and abandonment on its oil and gas
properties would be offset by salvage values received.  The adoption of SFAS 143 resulted in an increase
of total liabilities because retirement obligations are required to be recognized.

The estimated liability
is based on the Managing General Partner's historical experience in plugging and abandoning wells, estimated
remaining lives of those wells based on reserves estimates, external estimates as to the cost to plug and
abandon the wells in the future and federal and state regulatory requirements.  The liability is discounted
using an assumed credit-adjusted risk-free interest rate.  Revisions to the liability could occur due to changes
in estimates of plugging and abandonment costs or remaining lives of the wells, or if federal or state regulators
enact new plugging and abandonment requirements.

The adoption of
SFAS 143 as of January 1, 2003 resulted in a cumulative effect adjustment of (i) a $397,800
increase in non-current plugging and abandonment liabilities and (ii) a $397,800 cumulative effect
of change in accounting principle.  The pro forma effect of the application of SFAS 143 as if adopted
January 1, 2002 would be an increase of $213,600 ($142 per limited partner unit) to the partnerships net loss
or the year ended Decemebr 31, 2002.

The Partnership has no
assets legally restricted for purposes of settling asset retirement obligations.  Except for the item
previously referenced, the Partnership has determined that there are no other material retirement obligations
associated with long-lived assets.

A reconciliation
of the Partnership's liability for well plugging and abandonment costs for the year ended December 31, 2003
is as follows:

|Asset retirement obligations,
         December 31, 2002 |  | $ | -       |  | 
|-------------------------------------------------------- |  | - | ------- |  | 
|                                                        
|Adoption of SFAS 143                                     |  |   | 397,800 |  | 
|                                                        
|Accretion expense                                        |  |   | 23,900 
|                                                        
|Asset retirement obligations,
         December 31, 2003 |  | $ | 421,700 |  | 

Revenue Recognition

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

Recently Issued Financial Accounting
Standards

In
April 2003, the Financial Accounting Standards Board (FASB) issued SFAS No. 149 ("SFAS 149") "Amendment of Statement 133 on Derivative Instruments
and Hedging Activates."  SFAS 149 is effective for contracts entered into or modified after June 30, 2003
and amends and clarifies financial accounting and reporting for derivative instruments.  The adoption of
SFAS 149 did not have a material effect on the Partnership's financial position or results of operations.

In May 2003,
the FASB issued Statement No. 150 ("SFAS 150") "Accounting for Certain Financial Instruments with Characteristics
of Both Liabilities and Equity."  SFAS 150 requires that certain instruments taht were previously classified as equity on
a Partnership's statement of financial position now be classified as liabilities.  SFAS 150 is effective for
financial instruments entered into our modified after May 31, 2003, and otherwise is effective at the
beginning of the first interim period beginning after June 15, 2003.  The adoption of SFAS 150 did not
have an impact on the Partnership's results of operations or financial position.

---

Atlas America Public #9
Ltd
(A Pennsylvania Limited Partnership)

NOTES TO FINANCIAL
STATEMENTS  CONTINUED

December 31, 2003

NOTE 2 - SUMMARY OF SIGNIFICANT
ACCOUNTING POLICIES (Continued)

Environmental Matters

The
Partnership is subject to various federal, state and local laws and regulations relating to the protection
of the environment.  The Partnership has established procedures for the ongoing evaluation of its operations to identify
potential environmental exposures and to comply with regulatory policies and procedures.

The Partnership
accounts for environmental contingencies in accordance with SFAS No. 5 "Accounting for Contingencies."  Environmental
expenditures that relate to current operations are expensed or capitalized as appropriate.  Expenditures
that relate to an existing condition caused by past operations, and do not contribute to current or future
revenue generation, are expensed.  Liabilities are recorded when environmental assessments and/or clean-ups
are probable, and the costs can be reasonably estimated.  The Partnership maintains insurance that may cover in
whole or in part certain environmental expenditures.  For the two years ended December 31, 2003, the
Partnership had no environmental matters requiring specific disclsoure or requiring recording of a liability.

Major Customer

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.

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 and SFAS 149). These contracts qualify and have been designated as cash
flow hedges under SFAS 133 and accordingly, gain and losses resulting from market price
changes are deferred and recognized as a component of sales revenues in the month the gas
is sold. The Partnership has no derivatives at December 31, 2003.

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 limited partners generally participate in revenues and
costs in the following manner:

---

Atlas America Public #9
Ltd
(A Pennsylvania Limited Partnership)

NOTES TO FINANCIAL
STATEMENTS  CONTINUED

December 31, 2003

NOTE 4 - PARTICIPATION IN REVENUES
AND COSTS (Continued)

|                                          | Managing | 
|----------------------------------------- | -------- | 
|
|
|Organization and offering
         costs  |          | 
|Lease costs                               |          | 
|Revenues                                  |          | 
|Operating costs, administrative costs,    |          | 
|direct costs
         and all other costs |          | 
|Intangible drilling costs                 |          | 
|Tangible equipment costs                  |          | 
|                                         
|                                         

|(1) |  | Subject to the Managing General Partners subordination obligation,
               substantially all revenues will be credited as follows: before net of tax
               savings payout and partnership payout (as defined in the partnership agreement),
               partnership revenues will be shared in the same percentage as capital
               contributions are to the total partnership capital contributions. After net of
               tax savings payout, the Managing General Partner will receive an additional 6.5%
               of the partnership revenues, and after partnership payout, the Managing General
               Partner will receive an additional 8.5% of partnership revenues.
|--- |  | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------

|(2) |  | These costs will be charged to the partners in the same ratio as the related
               production revenues are credited.
|--- |  | -----------------------------------------------------------------------------------------------------------------------------

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 2003
and 2002 were $70,100 and $70,600, 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 2003 and 2002 were $232,100 and
$233,200, respectively
| | -----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------

| | Transportation fees paid to Atlas at $.35 per MCF. Transportation costs incurred in 2003 and 2002 were
$165,600 and $271,500, respectively.
| | -------------------------------------------------------------------------------------------------------------------------------------------

| | Our managing general partner and its affiliates are reimbursed for all direct costs expended
on our behalf.  During the years ended December 31, 2003 and 2002, our managing general partner received
$179,600 and $183,900, respectively, as reimbursement for direct costs.
| | -----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------

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.

---

Atlas America Public #9
Ltd
(A Pennsylvania Limited Partnership)

NOTES TO FINANCIAL
STATEMENTS  CONTINUED

December 31, 2003

NOTE 6  PURCHASE COMMITMENT

Subject to certain conditions, investor partners may present their interests beginning in 2005 for
purchase by Atlas. The purchase price will be calculated by Atlas in accordance with the terms of the
partnership agreement.Atlas is not obligated to purchase more than 5% of the units in any
calendar year. In the event that Atlas is unable to obtain the necessary funds, Atlas may
suspend its purchase obligation.

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

Under the terms of the partnership agreement, Atlas may be required to subordinate up to 50% of
its share of production revenues of the Partnership, net of related operating costs,
administrative costs and well supervision fees to the receipt by the investor partners of cash
distributions from the Partnership equal to at least 10% of their agreed subscriptions,
determined on a cumulative basis, in each of the first five years of Partnership
operations, commencing with the first distribution of revenues to the investor partners (July
2001). During the subordination period, Atlas can be reimbursed for any subordination
advances to the extent distributions exceed the 10% return. In 2003 and 2002, Atlas was
not required to subordinate any of its net revenues to the investor 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.

At December 31, 2003, Atlas had no open natural gas futures and option contracts covering
the Partnerships gas production and accordingly, had no unrealized loss or gains related to open NYMEX
contracts at that date.  The Partnerships net unrealized loss related to

---

Atlas America Public #9
Ltd
(A Pennsylvania Limited Partnership)

NOTES TO FINANCIAL
STATEMENTS  CONTINUED

December 31, 2003

NOTE 8  HEDGING ACTIVITIES
(Continued)

open NYMEX contracts was $125,700 at
December 31, 2002, which was recorded as a liability on the Partnerships balance sheet
and in partners capital as accumulated other comprehensive loss. The
unrealized loss at December 31, 2002 was reclassified to earnings during the year ended December 31, 2003.
The Partnership recognized losses of approximately $221,600  and $34,900 on settled contracts covering
natural gas production for the years ended December 31, 2003 and 2002, respectively, which are included
in natural gas and oil sales.

The Partnership recognized no gains or losses during the years ended December 31, 2003 and
2002 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

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 investor 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.

(1)      
Capitalized Costs

The following table presents the capitalized costs
related to natural gas and oil producing activities at December 31:

|                                                | 2003 | 2002
|----------------------------------------------- | ---- | ----
|Mineral interests in
         proved properties |      |     
|Wells and related equipment                     |      |     
|Accumulated depreciation and depletion          |      |     
|Net capitalized costs                           |      |     

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

The following table presents the results of
operations related to natural gas and oil production for the years ended December 31:

|                                                   | 2003 | 2002
|-------------------------------------------------- | ---- | ----
|Natural gas and oil sales                          |      |     
|Production costs                                   |      |     
|Accretion of asset retirement obligation           |      |     
|Depreciation and depletion and
         impairment |      |     
|Results of operations from oil and gas             |      |     
|producing activities                               |      |     

---

Atlas America Public #9
Ltd
(A Pennsylvania Limited Partnership)

NOTES TO FINANCIAL
STATEMENTS  CONTINUED

December 31, 2003

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

(3)      
Reserve Information (unaudited)

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.

|                                         | Natural Gas | Oil
|---------------------------------------- | ----------- | ---
|
|Proved developed reserves:               |             |    
|Balance, December 31, 2001               |             |    
|Production                               |             |    
|Revisions to previous
         estimates |             |    
|                                        
|Balance, December 31, 2002               |             |    
|Production                               |             |    
|Revisions to previous
         estimates |             |    
|                                        
|Balance, December 31, 2003               |             |    

---

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

None.

ITEM 8A.     
CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and
Procedures

Our Managing General Partner's 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) under the Securities Exchange Act of
1934) as of December 31, 2003.  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 evaluation date.

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(b) 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
that was the first of the Atlas group of companies, was incorporated in 1973. Atlas Energy
Group serves as our operator in Ohio. As of December 31, 2003, our managing general
partner and its affiliates had directly or through investments in partnerships similar to
our interest in approximately 5,300 wells of which, 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. We
depend on our parent company, Atlas America, for management and administrative functions
and financing our capital contributions. Resource America is currently offering a portion
of its common stock in Atlas America, the Delaware holding company, pursuant to an S-1
Registration Statement. If the offering is completed, Resource America will own
approximately 82.7% of the outstanding shares of Atlas Americas common stock and 80%
if the underwriters exercise their over-allotment option.

Resource
America has informed our managing general partner that it intends to distribute its
remaining ownership interest in Atlas America to its common stockholders. Resource America
expects the distributions to take the form of a spin-off by means of a special dividend to
Resource America common stockholders of all of Atlas Americas common stock owned by
Resource America. Resource America further has advised us that it anticipates that the
distribution will occur by the end of 2004. Resource America has sole discretion if and
when to complete the distribution and its terms. Resource America does not intend to
complete the distribution unless it receives a ruling from the Internal Revenue Service
and/or an opinion from its tax counsel as to the tax-free nature of the distribution to
Resource America and its stockholders for U.S. federal income tax purposes. The internal
Revenue Service requirements for tax-free distributions of this nature are complex and the
Internal Revenue Service has broad discretion, so there is significant uncertainty as to
whether Resource America will be able to obtain such ruling. Because of this uncertainty
and the fact that the timing and completion of the distribution is in Resource
Americas sole discretion, the distribution may not occur by the contemplated time or
may not occur at all.

Atlas
America is headquartered at 311 Rouser Road, Moon Township, Pennsylvania 15108, which is
also the managing general partners primary office.

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
|Freddie M. Kotek   |  | 48 
|                   |  |    
|Frank P. Carolas   |  | 44 
|Jeffrey C. Simmons |  | 45 
|Jack L. Hollander  |  | 48 
|Nancy J. McGurk    |  | 48 
|                   |  |    
|Michael L. Staines |  | 54 

---

With respect to the biographical information set
forth below:

   
  the approximate amount of an individuals professional time devoted to the business and affairs of the
managinggeneral partner and Atlas America have been aggregated because there is no reasonable method for them to distinguishtheir activities between the two companies; and

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

Freddie M. Kotek.President
and Chief Executive Officer since 2002 and Chairman of the Board of Directors since 2001.
Mr.Kotek has been Executive Vice President and Chief Financial Officer of Atlas America
since 2004 and served as a director from 2001 until 2004. Mr. Kotek has been a Senior Vice
President of Resource America, and President of Resource Leasing, Inc. (a wholly-owned
subsidiary of Resource America) since 1995. Mr. Kotek was President of Resource Properties
from 2000 to 2001 and its Executive Vice President from 1993 to 2000. Upon completion of
the Atlas America offering, Mr. Kotek intends to resign his positions at Resource America
and all of its subsidiaries which are not subsidiaries of Atlas 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. On completion of the Atlas America
offering Mr. Kotek will devote approximately 95% 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 2001. Mr. Carolas has been a Vice
President of Resource America and an Executive Vice President-Land and Geology of Atlas
America since 2001 and served as a Director of Atlas America from 2002 until 2004. Mr.
Carolas served as Vice President of Land and Geology for the managing general partner from
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. Upon completion of the Atlas America
offering, Mr. Carolas intends to resign his position at Resource America. Mr. Carolas is a
certified petroleum geologist and has been with the managing general partner 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.

Jeffrey C. Simmons.Executive
Vice President-Operations and a Director since January, 2001. Mr. Simmons has been a Vice
President of Resource America and an Executive Vice President of Atlas America since 2001
and was a Director of Atlas America from 2002 until 2004. Mr. Simmons served as Vice
President of Operations for the managing general partner from July 1999 until 2001 and for
Atlas America from 1998 until 2001. Mr. Simmons joined Resource America in 1986 as a
senior petroleum engineer and has served in various executive positions with its energy
subsidiaries since then. Upon completion of the Atlas America offering, Mr. Simmons
intends to resign his position at Resource America. 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 in 1981 and his Masters degree in Business Administration from Ashland University
in 1992. 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 2002 and before that served as Vice
President  Direct Participation Programs from 2001 until 2002. Mr. Hollander also
serves as Senior Vice President  Direct Participation Programs of Atlas America
since 2001. Mr. Hollander practiced law with Rattet, Hollander & Pasternak,
concentrating in tax matters and real estate transactions, from 1990 to 2001, and served
as in-house counsel for Integrated Resources, Inc. (a diversified financial services
company) from 1982 to 1990. 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.

Nancy J. McGurk.Senior Vice
President since 2002, Chief Financial Officer and Chief Accounting Officer since 2001. Ms.
McGurk also serves as Senior Vice President and Chief Accounting Officer of Atlas America
since January, 2002 and served as Chief Financial Officer from 2002 until 2004. Ms. McGurk
has been Vice President of Resource America since 1992 and its Treasurer and Chief
Accounting Officer since 1989. Upon completion of the Atlas America offering, Ms. McGurk
intends to resign her positions at Resource America. Also, since 1995 Ms. McGurk has
served as Vice President  Finance of Resource Energy, Inc. Ms. McGurk received a
Bachelor of Science degree in Accounting from Ohio State University in 1978, and has been
a Certified Public Accountant since 1982. On completion of the Atlas America offering Ms.
McGurk will devote approximately 80% 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 has been an Executive
Vice President of Atlas America since 1998. Mr. Staines has been a Senior Vice President
of Resource America since 1989 and was a director from 1989 to 2000 and Secretary from
1989 to 1998. Mr. Staines has been President of Atlas Pipeline Partners GP since 2001 and
its Chief Operating Officer and a member of its Managing Board since its formation in
1999. Upon completion of the Atlas America offering, Mr. Staines intends to resign his
position at Resource America. 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. On completion of the Atlas America offering Mr. Staines will
devote approximately 5% 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, 2003, we had issued and
outstanding 1,500 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 2005 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

ITEM 12.   CERTAIN RELATIONSHIPS AND
ELATED TRANSACTIONS

Oil and Gas Revenues.   Our managing
general partner is allocated 29.564% of our oil and gas
revenues in return for having paid organization and offering costs equal to 15% of our
subscriptions, 100% of tangible costs and contributing all leases for a total capital
contribution of $6,256,300. During the years ended December 31, 2003 and 2002, our
managing general partner received $749,100 and $824,800, 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 83 undeveloped prospects to drill
approximately 78.75 net wells and received a credit in the amount of $264,200.
During 2003 and 2002, 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, 2003 and 2002, our managing general partner received
$70,100 and $70,600, 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 years ended December 31, 2003 and 2002, our managing
general partner received $179,600 and $183,900, 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 80.75 net
wells. The total amount received by our managing general partner was $14,905,500 for
drilling and completing the wells. During 2003 and 2002, 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 calendar years
ended December 31, 2003 and 2002, our managing general partner received $232,100 and
$233,200, respectively, for well supervision fees.

---

Gathering Fees. We pay a combined
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 fiscal years ended December 31, 2003 and 2002 $165,600 and
$271,500 were paid respectively.

Other Compensation. For the years ended
December 31, 2003 and 2002, 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.

# ITEM 14. PRINCIPLE ACCOUNTANT FEES AND
SERVICES

Aggregate
fees recognized by the Partnership during the years ending December 31, 2003 and 2002 by its principal
accounting firm, Grant Thornton, L.L.P. are set forth below.  The audit committee of the managing general
partner considers whether any provisions of non-audit services is compatible with maintaining the principal
accountant's independence.

|                            | 2003 | 2002
|--------------------------- | ---- | ----
|                           
|Audit fees (2)              |      |     
|                           
|Total aggregate fees billed |      |     

(1)   Include the aggregate fees recognized in each of the last two years for
professional services rendered byGrant Thornton, L.L.P. for the audit of the
Partnership's annual financial statements and the review of financialstatements included in Form 10-Q.  The fees are for services that
are normally provided by Grant Thornton, L.L.Pin connection with statutory or regulatory filings or engagements.

Procedures
for Audit Committee Pre-Approval of Audit and Permissible Non-Audit Services of Independent Auditor.

Pursuant to
its charter, the Audit Committee of the managing general partner is responsible for reviewing and approving,
in advance, any audit and any permissible non-audit engagement or relationship between us and our independent auditors.

---

EXHIBIT INDEX

Description    Location

|      |                                                                  |                                 
|----- | ---------------------------------------------------------------- | --------------------------------
|4(a)  | Certificate of Limited
         Partnership for                  | Previously filed in
         the
|      | Atlas America Public #9 Ltd.                                     | Form 10-KSB for the             
|      |                                                                  | period ending December          
|      |                                                                  | 31, 2000                        
|     
|4(b)  | Amended and Restated Certificate
         and Agreement          | Previously filed in
         the
|      | of Limited Partnership for Atlas
         America Public #9 Ltd. | Form 10-KSB for the             
|      |                                                                  | period ending December          
|      |                                                                  | 31, 2000                        
|10(a) | Drilling and Operating Agreement
         with exhibits          | Previously filed in
         the
|      |                                                                  | Form 10-KSB for the             
|      |                                                                  | period ending December          
|      |                                                                  | 31, 2000                        

31.1     Certification Pursuant
to Rule 13a-15(e)/15(d) - 15(e).

31.2     Certification Pursuant
to Rule 13a-15(e)/15(d) - 15(e).

32.1     Certification Pursuant
to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of The Sarbanes-Oxley Act of2002.

33.2     Certification Pursuant
to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of The Sarbanes-Oxley Act of2002.

---

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 America Public #9
Ltd.

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

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

Date:  March 29, 2004

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

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

Date:  March 29, 2004

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

Date:   March 29, 2004

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

Date:   March 29, 2004

By  (Signature and Title):Nancy J. McGurk, Vice President, Chief Financial Officerand Chief Accounting Officer

Date:  March 29, 2004

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.