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United States
Securities and Exchange Commission
 Washington, D.C. 20549
 Form 10-K
  þ
    
    ANNUAL REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934
 For the fiscal year ended December 31, 2010
 o
    
    TRANSITION REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934
 For the transition period from  to
 Commission file number 000-49776
 ATLAS AMERICA PUBLIC #9 LTD.
  Pennsylvania
    
    25-1867510(State or other jurisdiction of
    
    (I.R.S. Employerincorporation or organization)
    
    Identification No.)Westpointe Corporate Center One1550 Coraopolis Heights Rd. 2nd FloorMoon Township, PA
    
    15108(Address of principal executive offices)
    
    (zip code)
 (412) 262-2830
  Title of each class
    
    Name of each exchange on which registeredNone
    
    None
 
 o þ
 o þ
 þ o
 þ
  Large accelerated filer o
    
    Accelerated filer o
    
    Non-accelerated filer o
    
    Smaller reporting company þ
 o þ




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##### 



ATLAS AMERICA PUBLIC #9 LTD.
(A PENNSYLVANIA LIMITED PARTNERSHIP)
INDEX TO ANNUAL REPORT
ON FORM 10-K
 PAGEPART IItem 1: Business
    
    
    3-5Item 2: Properties
    
    
    6-9Item 3: Legal Proceedings
    
    
    9Item 4: (Removed and Reserved)
    
    
    9PART IIItem 5: Market for Registrants Common Equity and Related Security Holder Matters
    
    
    10Item 7: Managements Discussion and Analysis of Financial Condition or Plan of Operations
    
    
    10-14Item 8: Financial Statements
    
    
    15-35Item 9: Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
    
    
    35Item 9A: Controls and Procedures
    
    
    35-36Item 9B: Other Information
    
    
    36PART IIIItem 10: Directors and Executive Officers of the Registrant
    
    
    36-38Item 11: Executive Compensation
    
    
    38Item 12: Security Ownership of Certain Beneficial Owners and Management
    
    
    38Item 13: Certain Relationships and Related Party Transactions
    
    
    38Item 14: Principal Accountant Fees and Services
    
    
    39PART IVItem 15: Exhibits
    
    
    39SIGNATURES
    
    
    40Exhibit 23.1Exhibit 31.1Exhibit 31.2Exhibit 32.1Exhibit 32.2Exhibit 99.1
   2




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The matters discussed within this report include forward-looking statements. These statements
may be identified by the use of forward-looking terminology such as anticipate, believe,
continue, could, estimate, expect, intend, may, might, plan, potential,
predict, should, or will, or the negative thereof or other variations thereon or comparable
terminology. In particular, statements about our expectations, beliefs, plans, objectives,
assumptions or future events or performance contained in this report are forward-looking
statements. We have based these forward-looking statements on our current expectations,
assumptions, estimates, and projections. While we believe these expectations, assumptions,
estimates, and projections are reasonable, such forward-looking statements are only predictions and
involve known and unknown risks and uncertainties, many of which are beyond our control. These and
other important factors may cause our actual results, performance or achievements to differ
materially from any future results, performance or achievements expressed or implied by these
forward-looking statements.
 
 PART I
 
 ITEM 1.
    
    BUSINESS
 General.
      3




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
    
    well tending, routine maintenance and adjustment;
 
    
    reading meters, recording production, pumping, maintaining appropriate books and
records; and
 
    
    preparation of reports for us and to government agencies.
   Markets and Competition .
  Governmental Regulation.
 Regulation of oil and gas producing activities .
  4




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
    
    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 .
  Where can you find more information.
  
  5




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ITEM 2.
    
    PROPERTIES
 Drilling Activity
 Summary of Producing Wells.
 Number of Producing WellsGross
    
    
    NetGas
    
    
    78
    
    
    
    73.75Oil
    
    
    4
    
    
    
    4.00Total
    
    
    82
    
    
    
    77.75
 Production.
 AverageYear
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    Production CostEnded
    
    Production
    
    
    Average Sales Price
    
    
    (Lifting Cost)December 31,
    
    Oil (bbls) (1)
    
    
    Gas (mcf) (1)
    
    
    per bbl (1)
    
    
    per mcf (1)
    
    
    per mcfe (1) (2)2010
    
    
    1,400
    
    
    
    181,800
    
    
    $
    76.64
    
    
    $
    6.86
    
    
    $
    2.972009
    
    
    2,000
    
    
    
    179,500
    
    
    $
    62.73
    
    
    $
    8.08
    
    
    $
    3.39
 
 (1)
    
    Mcf represents one thousand cubic feet of natural gas. Mcfe represents 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, production taxes, insurance and
gathering charges. Natural Gas and Oil Reserve Information.
 
    
    Introduce a new definition of oil and gas producing activities. This new definition
allows companies to include in their reserve base volumes from unconventional resources.
Such unconventional resources include bitumen extracted from oil sands and oil and gas
extracted from coal beds and shale formations.
 
    
    Report oil and gas reserves using an unweighted average price using the prior 12-month
period, based on the closing prices on the first day of each month, rather than year-end
pricing. This should maximize the comparability of reserve estimates among companies and
mitigate the distortion of the estimates that arises when using a single pricing date.
 
    
    Permit companies to disclose their probable and possible reserves on a voluntary basis.
Current rules limit disclosure to only proved reserves.
 
    
    Update and revise reserve definitions to reflect changes in the oil and gas industry and
new technologies. New updated definitions include by geographic area and reasonable
certainty.
 
    
    Permit the use of new technologies to determine proved reserves if those technologies
have been demonstrated empirically to lead to reliable conclusions about reserves volumes.
 
    
    Require additional disclosures regarding the qualifications of the chief technical
person who oversees the companys overall reserve estimation process. Additionally,
disclosures are required related to internal controls over reserve estimation, as well as a
report addressing the independence and qualifications of a companys reserves preparer or
auditor based on Society of Petroleum Engineers criteria.
  6




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December 31,2010
    
    
    2009Natural gas (per mcf)
    
    $
    4.38
    
    
    $
    3.87Oil ( per bbl)
    
    
    79.43
    
    
    
    61.18
   7




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At December 31,2010
    
    
    2009Natural gas reserves  proved developed reserves (Mcf) (1) (2) (4)
    
    
    1,446,500
    
    
    
    1,515,200Oil reserves  proved developed reserves (Bbl) (1) (2) (4)
    
    
    14,000
    
    
    
    11,900Total proved reserves (Mcfe)
    
    
    1,530,500
    
    
    
    1,586,600PV-10 estimate of cash flows of proved reserves (3)(4)
    
    $
    1,897,500
    
    
    $
    1,697,300PV-10 estimate per limited partner unit (5)
    
    $
    816
    
    
    $
    730Undiscounted estimate per limited partner unit (5)
    
    $
    1,257
    
    
    $
    1,086
 
 (1)
    
    Proved reserves generally refers to 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 refers to reserves that can be
expected to be recovered through existing wells with existing equipment and operating
methods.(3)
    
    The present value of estimated future net cash flows is calculated by
discounting estimated future net cash flows by 10% annually.(4)
    
    Please see Regulation S-X rule 4-10 for complete definitions of each reserve
category.(5)
    
    This value per $10,000 unit is determined by following the methodology used for
determining our proved reserves using the data discussed above. However, this value does
not necessarily reflect the fair market value of a unit, and each unit is illiquid.
Also, the value of a unit for purposes of presentment of the unit to our MGP for
purchase is different, because it is calculated under a formula set forth in the
Partnership Agreement.  Title to Properties
  Acreage
 Developed AcreageLocation
    
    Gross (1)
    
    
    Net (2)Pennsylvania
    
    
    1,837.23
    
    
    
    1,804.08Ohio
    
    
    876.24
    
    
    
    802.92Total
    
    
    2,713.47
    
    
    
    2,607.00
 
 (1)
    
    A gross acre is an acre in which we own a working interest.(2)
    
    A net acre represents 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.  8




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Delivery Commitments
    
 ITEM 3.
    
    LEGAL PROCEEDINGS
   
 ITEM 4.
    
    (REMOVED AND RESERVED)
   9




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PART II
 
 ITEM 5.
    
    MARKET FOR REGISTRANTS COMMON EQUITY AND RELATED SECURITY HOLDER MATTERS
 Market Information.
 
    
    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.
  
    
    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 the substitution and to confirm his or her agreement to be bound by
the terms of our partnership agreement.
  Holders.
 Distributions.
   
    
    $476,600 and $690,400 to our limited partners; and
 
    
    $262,300 and $380,000 to our managing general partner, respectively.
 
 ITEM 7.
    
    MANAGEMENTS DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION OR
PLAN OF OPERATIONS
   10




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Results of Operations.
 Years Ended December 31,2010
    
    
    2009Production revenues (in thousands):Gas
    
    $
    1,247
    
    
    $
    1,451Oil
    
    
    106
    
    
    
    125Total
    
    $
    1,353
    
    
    $
    1,576Production volumes:Gas (mcf/day) (1)
    
    
    498
    
    
    
    492Oil (bbls/day) (1)
    
    
    4
    
    
    
    5Total (mcfe/day) (1)
    
    
    522
    
    
    
    522Average sales price:Gas (per mcf) (1)
    
    $
    6.86
    
    
    $
    8.08Oil (per bbl) (1)
    
    $
    76.64
    
    
    $
    62.73Average production costs:As a percent of revenues
    
    
    42
    %
    
    
    41
    %Per mcfe (1)
    
    $
    2.97
    
    
    $
    3.39Depletion per mcfe
    
    $
    3.66
    
    
    $
    2.89
 
 (1)
    
    Mcf represents thousand cubic feet, mcfe represents thousand cubic feet
equivalent, and bbls represents barrels. Bbls are converted to mcfe using the ratio of
six mcfs to one bbl. Natural Gas Revenues.
  11




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Oil Revenues .
 Expenses.
    Liquidity and Capital Resources .
     12




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Critical Accounting Policies
 Use of estimates.
 Impairment of Long-Lived Assets.
 Fair Value of Financial Instruments
  Level 1 
 Level 2 
 Level 3
    13




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Reserve Estimates .
 Asset Retirement Obligations
 Working Interest .
  14




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ITEM 8.
    
    FINANCIAL STATEMENTS
 REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
 
     
  15




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ATLAS AMERICA PUBLIC #9 LTD.
BALANCE SHEETS
DECEMBER 31,
 2010
    
    
    2009ASSETSCurrent assets:Cash and cash equivalents
    
    $
    81,700
    
    
    $
    81,700Accounts receivable-affiliate
    
    
    263,300
    
    
    
    340,500Short-term hedge receivable due from affiliate
    
    
    243,900
    
    
    
    243,000Total current assets
    
    
    588,900
    
    
    
    665,200Oil and gas properties net
    
    
    5,655,500
    
    
    
    7,177,300Long-term hedge receivable due from affiliate
    
    
    238,600
    
    
    
    199,500$
    6,483,000
    
    
    $
    8,042,000LIABILITIES AND PARTNERS CAPITALCurrent liabilities:Accrued liabilities
    
    $
    11,000
    
    
    $
    21,100Short-term hedge liability due to affiliate
    
    
    3,800
    
    
    
    2,900Total current liabilities
    
    
    14,800
    
    
    
    24,000Asset retirement obligation
    
    
    1,051,200
    
    
    
    884,800Long-term hedge liability due to affiliate
    
    
    43,800
    
    
    
    31,700Partners capital:Managing general partner
    
    
    1,599,600
    
    
    
    2,006,900Limited partners (1,500 units)
    
    
    3,445,300
    
    
    
    4,686,700Accumulated other comprehensive income
    
    
    328,300
    
    
    
    407,900Total partners capital
    
    
    5,373,200
    
    
    
    7,101,500$
    6,483,000
    
    
    $
    8,042,000
   16




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ATLAS AMERICA PUBLIC #9 LTD.
STATEMENTS OF OPERATIONS
YEARS ENDED DECEMBER 31, 2010 and 2009
 2010
    
    
    2009REVENUESNatural gas and oil
    
    $
    1,352,800
    
    
    $
    1,575,700Interest income
    
    
    200
    
    
    
    400Total revenues
    
    
    1,353,000
    
    
    
    1,576,100COSTS AND EXPENSESProduction
    
    
    565,400
    
    
    
    649,200Depletion
    
    
    695,700
    
    
    
    554,000Impairment
    
    
    832,900
    
    
    
    Accretion of asset retirement obligation
    
    
    53,000
    
    
    
    44,700General and administrative
    
    
    115,800
    
    
    
    115,800Total expenses
    
    
    2,262,800
    
    
    
    1,363,700Net (loss) earnings
    
    $
    (909,800
    )
    
    $
    212,400Allocation of net (loss) earnings:Managing general partner
    
    $
    (145,000
    )
    
    $
    143,200Limited partners
    
    $
    (764,800
    )
    
    $
    69,200Net (loss) earnings per limited partnership unit
    
    $
    (510
    )
    
    $
    46
   17




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ATLAS AMERICA PUBLIC #9 LTD.
STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
YEARS ENDED DECEMBER 31, 2010 and 2009
 2010
    
    
    2009Net (loss) earnings
    
    $
    (909,800
    )
    
    $
    212,400Other comprehensive loss:Unrealized holding gain on hedging contracts
    
    
    266,000
    
    
    
    331,200Less: reclassification adjustment for gains realized in net earnings
    
    
    (345,600
    )
    
    
    (523,000
    )Total other comprehensive loss
    
    
    (79,600
    )
    
    
    (191,800
    )Comprehensive (loss) income
    
    $
    (989,400
    )
    
    $
    20,600
   18




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ATLAS AMERICA PUBLIC #9 LTD.
STATEMENTS OF CHANGES IN PARTNERS CAPITAL
YEARS ENDED DECEMBER 31, 2010 and 2009
 AccumulatedManaging
    
    
    
    
    
    
    OtherGeneral
    
    
    Limited
    
    
    ComprehensivePartner
    
    
    Partners
    
    
    Income (Loss)
    
    
    TotalBalance at December 31, 2008
    
    $
    2,243,700
    
    
    $
    5,307,900
    
    
    $
    599,700
    
    
    $
    8,151,300Participation in revenue and expenses:Net production revenues
    
    
    328,900
    
    
    
    597,600
    
    
    
    
    
    
    
    926,500Interest income
    
    
    200
    
    
    
    200
    
    
    
    
    
    
    
    400Depletion
    
    
    (128,900
    )
    
    
    (425,100
    )
    
    
    
    
    
    
    (554,000
    )Accretion of asset retirement obligations
    
    
    (15,900
    )
    
    
    (28,800
    )
    
    
    
    
    
    
    (44,700
    )General and administrative
    
    
    (41,100
    )
    
    
    (74,700
    )
    
    
    
    
    
    
    (115,800
    )Net earnings
    
    
    143,200
    
    
    
    69,200
    
    
    
    
    
    
    
    212,400Other comprehensive loss
    
    
    
    
    
    
    
    
    
    
    (191,800
    )
    
    
    (191,800
    )Distributions to partners
    
    
    (380,000
    )
    
    
    (690,400
    )
    
    
    
    
    
    
    (1,070,400
    )Balance at December 31, 2009
    
    $
    2,006,900
    
    
    $
    4,686,700
    
    
    $
    407,900
    
    
    $
    7,101,500Participation in revenue and expenses:Net production revenues
    
    
    279,500
    
    
    
    507,900
    
    
    
    
    
    
    
    787,400Interest income
    
    
    100
    
    
    
    100
    
    
    
    
    
    
    
    200Depletion
    
    
    (166,000
    )
    
    
    (529,700
    )
    
    
    
    
    
    
    (695,700
    )Impairment
    
    
    (198,700
    )
    
    
    (634,200
    )
    
    
    
    
    
    
    (832,900
    )Accretion of asset retirement obligations
    
    
    (18,800
    )
    
    
    (34,200
    )
    
    
    
    
    
    
    (53,000
    )General and administrative
    
    
    (41,100
    )
    
    
    (74,700
    )
    
    
    
    
    
    
    (115,800
    )Net loss
    
    
    (145,000
    )
    
    
    (764,800
    )
    
    
    
    
    
    
    (909,800
    )Other comprehensive loss
    
    
    
    
    
    
    
    
    
    
    (79,600
    )
    
    
    (79,600
    )Distributions to partners
    
    
    (262,300
    )
    
    
    (476,600
    )
    
    
    
    
    
    
    (738,900
    )Balance at December 31, 2010
    
    $
    1,599,600
    
    
    $
    3,445,300
    
    
    $
    328,300
    
    
    $
    5,373,200
   19




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ATLAS AMERICA PUBLIC #9 LTD.
STATEMENTS OF CASH FLOWS
YEARS ENDED DECEMBER 31, 2010 and 2009
 2010
    
    
    2009Cash flows from operating activities:Net (loss) earnings
    
    $
    (909,800
    )
    
    $
    212,400Adjustments to reconcile net (loss) earnings to net cash
provided by operating activities:Depletion
    
    
    695,700
    
    
    
    554,000Non-cash on derivative value
    
    
    (106,600
    )
    
    
    Impairment of oil and gas properties
    
    
    939,500
    
    
    
    Accretion of asset retirement obligation
    
    
    53,000
    
    
    
    44,700Decrease in accounts receivable-affiliate
    
    
    77,200
    
    
    
    128,500Decrease in accrued liabilities
    
    
    (10,100
    )
    
    
    (1,100
    )Net cash provided by operating activities
    
    
    738,900
    
    
    
    938,500Cash flows from financing activities:Distributions to partners
    
    
    (738,900
    )
    
    
    (1,070,400
    )Net cash used in financing activities
    
    
    (738,900
    )
    
    
    (1,070,400
    )Net decrease in cash and cash equivalents
    
    
    
    
    
    
    (131,900
    )Cash and cash equivalents at beginning of year
    
    
    81,700
    
    
    
    213,600Cash and cash equivalents at end of year
    
    $
    81,700
    
    
    $
    81,700Supplemental Schedule of non-cash investing and financing activities:Asset retirement obligation revision
    
    $
    113,400
    
    
    $
    95,700
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ATLAS AMERICA PUBLIC #9 LTD.
NOTES TO FINANCIAL STATEMENTS
DECEMBER 31, 2010 AND 2009
 NOTE 1  DESCRIPTION OF BUSINESS
   NOTE 2  SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
  Use of Estimates
   Accounts Receivable and Allowance for Possible Losses.
   21




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ATLAS AMERICA PUBLIC #9 LTD.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2010 AND 2009
 NOTE 2  SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
 Fair Value of Financial Instruments
  Supplemental Cash Flow Information
  Concentration of Credit Risk
  Oil and Gas Properties
   Impairment of Long-Lived Assets
   22




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ATLAS AMERICA PUBLIC #9 LTD.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2010 AND 2009
 NOTE 2  SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
 Impairment of Long-Lived Assets (Continued)
    Working Interest
  Revenue Recognition
   23




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ATLAS AMERICA PUBLIC #9 LTD.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2010 AND 2009
 NOTE 2  SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
 Revenue Recognition (Continued)
  Asset Retirement Obligation
  Environmental Matters
   Comprehensive Income (Loss)
   24




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ATLAS AMERICA PUBLIC #9 LTD.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2010 AND 2009
 NOTE 2  SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
 Recently Adopted Accounting Standards
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ATLAS AMERICA PUBLIC #9 LTD.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2010 AND 2009
 NOTE 2  SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
 Major Customers
  Income Taxes
  NOTE 3  PARTICIPATION IN REVENUES AND COSTS
  ManagingGeneral
    
    
    LimitedPartner
    
    
    PartnersOrganization and offering costs
    
    
    100
    %
    
    
    0
    %Lease costs
    
    
    100
    %
    
    
    0
    %Revenues (1)
    
    
    35.5
    %
    
    
    64.5
    %Operating costs, administrative costs, direct and all other costs (2)
    
    
    35.5
    %
    
    
    64.5
    %Intangible drilling costs
    
    
    0
    %
    
    
    100
    %Tangible equipment costs
    
    
    100
    %
    
    
    0
    %
 
 (1)
    
    Subject to the MGPs subordination obligation, substantially all partnership revenues
will be shared in the same percentage as capital contributions are to the total
partnership capital contributions, except that the MGP will receive an additional 7% of
the partnership revenues.(2)
    
    These costs will be charged to the partners in the same ratio as the related
production revenues are credited.  26




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ATLAS AMERICA PUBLIC #9 LTD.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2010 AND 2009
 NOTE 4  OIL AND GAS PROPERTIES
  December 31,2010
    
    
    2009Natural gas and oil properties:Proved properties:Leasehold interests
    
    $
    257,800
    
    
    $
    257,800Wells and related equipment
    
    
    18,479,300
    
    
    
    18,365,90018,737,100
    
    
    
    18,623,700Accumulated depletion
    
    
    (13,081,600
    )
    
    
    (11,446,400
    )$
    5,655,500
    
    
    $
    7,177,300
 NOTE 5  ASSET RETIREMENT OBLIGATION
    Years Ended December 31,2010
    
    
    2009Asset retirement obligation at beginning of year
    
    $
    884,800
    
    
    $
    744,400Revisions in estimates
    
    
    113,400
    
    
    
    95,700Accretion expense
    
    
    53,000
    
    
    
    44,700Total asset retirement obligations at end of year
    
    $
    1,051,200
    
    
    $
    884,800
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ATLAS AMERICA PUBLIC #9 LTD.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2010 AND 2009
 NOTE 6  DERIVATIVE INSTRUMENTS
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ATLAS AMERICA PUBLIC #9 LTD.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2010 AND 2009
 NOTE 6  DERIVATIVE INSTRUMENTS (Continued)
  Fair Value of Derivative Instruments:
 Asset Derivatives
    
    
    
    
    
    
    Liability DerivativesDerivatives in
    
    
    
    
    
    Fair Value
    
    
    
    
    
    
    Fair ValueCash Flow
    
    Balance Sheet
    
    December 31,
    
    
    December 31,
    
    
    Balance sheet
    
    December 31,
    
    
    December 31,Hedging Relationships
    
    Location
    
    2010
    
    
    2009
    
    
    Location
    
    2010
    
    
    2009Commodity Contracts
    
    Current Assets
    
    $
    243,900
    
    
    $
    243,000
    
    
    Current liabilities
    
    $
    (3,800
    )
    
    $
    (2,900
    )Long-Term Assets
    
    
    238,600
    
    
    
    199,500
    
    
    Long-term liabilities
    
    
    (43,800
    )
    
    
    (31,700
    )Total Derivatives
    
    
    
    
    
    $
    482,500
    
    
    $
    442,500
    
    
    
    
    
    
    $
    (47,600
    )
    
    $
    (34,600
    )
 Effects of Derivative Instruments on statements of operations:
 Gain
    
    
    
    
    
    
    GainRecognized in OCI on Derivative
    
    
    
    
    
    
    Reclassified from OCI into (Loss) Income(Effective Portion)
    
    
    Location of Gain/Loss
    
    
    (Effective Portion)Derivatives in
    
    Twelve Months Ended
    
    
    Reclassified from Accumulated
    
    
    Twelve Months EndedCash Flow
    
    December 31,
    
    
    December 31,
    
    
    OCI into Income
    
    
    December 31,
    
    
    December 31,Hedging Relationships
    
    2010
    
    
    2009
    
    
    (Effective Portion)
    
    
    2010
    
    
    2009Commodity Contracts
    
    $
    266,000
    
    
    $
    331,200
    
    
    Natural Gas and Oil Revenue
    
    
    $
    345,600
    
    
    $
    523,000
    Natural Gas Fixed Price Swaps
 Production
    
    
    
    
    
    AveragePeriod Ending
    
    Volumes
    
    
    Fixed Price
    
    
    Fair ValueDecember 31,
    
    (MMbtu) (1)
    
    
    (per MMbtu) (1)
    
    
    Asset(2)2011
    
    
    70,000
    
    
    $
    6.964
    
    
    $
    171,5002012
    
    
    39,400
    
    
    
    7.485
    
    
    
    94,1002013
    
    
    25,600
    
    
    
    6.803
    
    
    
    35,5002014
    
    
    12,000
    
    
    
    5.942
    
    
    
    4,800$
    305,900
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ATLAS AMERICA PUBLIC #9 LTD.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2010 AND 2009
 NOTE 6  DERIVATIVE INSTRUMENTS (Continued)
 Natural Gas Costless Collars
 Production
    
    
    
    
    
    
    
    
    
    AveragePeriod Ending
    
    Option
    
    
    Volumes
    
    
    Floor & Cap
    
    
    Fair ValueDecember 31,
    
    Type
    
    
    (MMbtu) (1)
    
    
    (per MMbtu) (1)
    
    
    Asset/(Liability)(2)2011
    
    Puts purchased
    
    
    34,300
    
    
    $
    6.535
    
    
    $
    71,5002011
    
    Calls sold
    
    
    34,300
    
    
    
    7.653
    
    
    
    (900
    )2012
    
    Puts purchased
    
    
    21,100
    
    
    
    6.102
    
    
    
    31,8002012
    
    Calls sold
    
    
    21,100
    
    
    
    7.328
    
    
    
    (5,400
    )2013
    
    Puts purchased
    
    
    35,800
    
    
    
    5.862
    
    
    
    51,7002013
    
    Calls sold
    
    
    35,800
    
    
    
    7.043
    
    
    
    (22,800
    )2014
    
    Puts purchased
    
    
    12,400
    
    
    
    5.705
    
    
    
    17,7002014
    
    Calls sold
    
    
    12,400
    
    
    
    6.811
    
    
    
    (11,600
    )$
    132,000
 Crude Oil Fixed Price Swaps
 Production
    
    
    
    
    
    AveragePeriod Ending
    
    Volumes
    
    
    Fixed Price
    
    
    Fair ValueDecember 31,
    
    (Bbl) (1)
    
    
    (per Bbl) (1)
    
    
    Asset(3)2011
    
    
    200
    
    
    $
    87.703
    
    
    $
    (1,400
    )2012
    
    
    200
    
    
    
    87.299
    
    
    
    (1,200
    )2013
    
    
    100
    
    
    
    87.632
    
    
    
    (300
    )2014
    
    
    
    
    
    
    
    
    
    
    $
    (2,900
    )
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ATLAS AMERICA PUBLIC #9 LTD.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2010 AND 2009
 NOTE 6  DERIVATIVE INSTRUMENTS (Continued)
 Crude Oil Costless Collars
 Production
    
    
    
    
    
    
    
    
    
    AveragePeriod Ending
    
    Option
    
    
    Volumes
    
    
    Floor & Cap
    
    
    Fair ValueDecember 31,
    
    Type
    
    
    (Bbl) (1)
    
    
    (per Bbl) (1)
    
    
    Asset/(Liability) (3)2011
    
    Puts purchased
    
    
    150
    
    
    $
    76.818
    
    
    $
    3002011
    
    Calls sold
    
    
    150
    
    
    
    100.965
    
    
    
    (1,000
    )2012
    
    Puts purchased
    
    
    100
    
    
    
    76.143
    
    
    
    7002012
    
    Calls sold
    
    
    100
    
    
    
    101.596
    
    
    
    (1,200
    )2013
    
    Puts purchased
    
    
    50
    
    
    
    76.148
    
    
    
    3002013
    
    Calls sold
    
    
    50
    
    
    
    102.587
    
    
    
    (400
    )2014
    
    Puts purchased
    
    
    
    
    
    
    
    
    
    
    2014
    
    Calls sold
    
    
    
    
    
    
    
    
    
    
    $
    (1,300
    )Total Net Asset
    
    
    $
    433,700
 
 (1)
    
    MMBTU represents million British Thermal Units. Bbl represents barrels.(2)
    
    Fair value based on forward NYMEX natural gas prices, as applicable.(3)
    
    Fair value based on forward WTI crude oil prices, as applicable. NOTE 7  FAIR VALUE OF FINANCIAL INSTRUMENTS
  Level 1
 Level 2
 Level 3
 Assets and Liabilities Measured at Fair Value on a Recurring Basis
   31




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ATLAS AMERICA PUBLIC #9 LTD.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2010 AND 2009
 NOTE 7  FAIR VALUE OF FINANCIAL INSTRUMENTS (Continued)
 Assets and Liabilities Measured at Fair Value on a Non-Recurring Basis
  NOTE 8  CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS
  
    
    Administrative costs which are included in general and administrative expenses in
the Partnerships statements of operations are payable at $75 per well per month for
the years ended December 31, 2010 and 2009, respectively, were $67,400 and $67,100,
respectively.
 
    
    Monthly well supervision fees which are included in production expenses in the
Partnerships statements of operations are payable at $337 per well per month in 2010
and 2009, respectively, for operating and maintaining the wells. Well supervision fees
incurred for the years ended December 31, 2010 and 2009 were $303,300 and $301,600,
respectively.
 
    
    Transportation fees which are included in production expenses in the Partnerships
statements of operations are generally payable at 13% of the natural gas sales price.
Transportation fees incurred for the years ended December 31, 2010 and 2009 were
$146,200 and $172,200, respectively.
 
    
    Direct costs which are included in production and general administrative expenses in
the Partnerships statements of operations are payable to the MGP and its affiliates as
reimbursement for all costs expended on the Partnerships behalf. Direct costs incurred
for the years ended December 31, 2010 and 2009 were $164,300 and $224,100,
respectively.
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ATLAS AMERICA PUBLIC #9 LTD.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2010 AND 2009
 NOTE 9  COMMITMENTS AND CONTINGENCIES
   Legal Proceedings
   NOTE 10  NATURAL GAS AND OIL PRODUCING ACTIVITIES (UNAUDITED)
 (1)
    
    Capitalized Costs Related to Oil and Gas Producing Activities
  At December 31,2010
    
    
    2009Leasehold interests
    
    $
    257,800
    
    
    $
    257,800Wells and related equipment
    
    
    18,479,300
    
    
    
    18,365,900Accumulated depletion
    
    
    (13,081,600
    )
    
    
    (11,446,400
    )Net capitalized cost
    
    $
    5,655,500
    
    
    $
    7,177,300
 (2)
    
    Oil and Gas Reserve Information
   33




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ATLAS AMERICA PUBLIC #9 LTD.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2010 AND 2009
 NOTE 10  NATURAL GAS AND OIL PRODUCING ACTIVITIES (UNAUDITED) (Continued)
   Natural Gas
    
    
    Oil(Mcf)
    
    
    (Bbls)Proved developed reserves:Balance at December 31, 2008
    
    
    2,381,000
    
    
    
    14,500Production
    
    
    (179,500
    )
    
    
    (2,000
    )Revisions to previous estimates
    
    
    (686,300
    )
    
    
    (600
    )Balance at December 31, 2009
    
    
    1,515,200
    
    
    
    11,900Production
    
    
    (181,800
    )
    
    
    (1,400
    )Revisions to previous estimates
    
    
    113,100
    
    
    
    3,500Balance at December 31, 2010
    
    
    1,446,500
    
    
    
    14,000
 NOTE 11  SUBSEQUENT EVENTS
 Atlas Energy, Inc. Asset Acquisition
  Laurel Mountain Sale
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ATLAS AMERICA PUBLIC #9 LTD.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2010 AND 2009
 NOTE 11  SUBSEQUENT EVENTS (Continued)
 Hedge Monetization
  
 ITEM 9.
    
    CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
  
 ITEM 9A.
    
    CONTROLS AND PROCEDURES
 Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures
   Managements Report on Internal Control over Financial Reporting
 Internal Control  Integrated
Framework
  35




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ITEM 9B.
    
    OTHER INFORMATION
  
 PART III
 
 ITEM 10.
    
    DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
 nd
 Executive Officers and Directors.
 NAME
    
    AGE
    
    
    POSITION OR OFFICEFreddie M. Kotek
    
    
    55
    
    
    Chairman of the Board of Directors, Chief Executive Officer and PresidentJeffrey C. Simmons
    
    
    52
    
    
    Executive Vice President  Operations and a DirectorJack L. Hollander
    
    
    54
    
    
    Senior Vice President  Direct Participation ProgramsSean P. McGrath
    
    
    39
    
    
    Chief Financial Officer
  
    
    the approximate amount of an individuals professional time devoted to the business
and affairs of our MGP and Atlas Energy have been aggregated because there is no
reasonable method for them to distinguish their activities between the two companies;
and
 
    
    for those individuals who also hold senior positions with other affiliates of our
MGP, if it is stated that they devote approximately 100% of their professional time to
our MGP and Atlas Energy, it is because either the other affiliates are not currently
active in drilling new wells, such as Viking Resources or Resource Energy, and the
individuals are not required to devote a material amount of their professional time to
the affiliates, or there is no reasonable method to distinguish their activities between
our MGP and Atlas Energy as compared with the other affiliates of our MGP, such as
Viking Resources or Resource Energy.
  36




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Freddie M. Kotek
 Jeffrey C. Simmons.
 Jack L. Hollander.
 Sean P. McGrath.
 Audit Committee Financial Expert.
 Remuneration of Officers and Directors.
  37




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Code of Business Conduct and Ethics. nd
 
 ITEM 11.
    
    EXECUTIVE COMPENSATION
  
 ITEM 12.
    
    SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
  
 ITEM 13.
    
    CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS
 Oil and Gas Revenues.
 Administrative Costs.
 Direct Costs.
 Well Charges.
 Transportation Fees.
 Other Compensation.
  38




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ITEM 14.
    
    PRINCIPAL ACCOUNTANT FEES AND SERVICES
 Audit Fees.
 Procedures for Audit Committee Pre-Approval of Audit and Permissible Non-Audit Services of
Independent Auditor.
 
 PART IV
 
 ITEM 15.
    
    EXHIBITS
 
 EXHIBIT INDEX
 Description
    
    Location4
    (a)
    
    Certificate of Limited Partnership for Atlas America
Public #9 Ltd.
    
    Previously filed in our Form 10 KSB for the
period ending December 31, 20004
    (b)
    
    Amended and Restated Certificate and Agreement
of Limited Partnership for Atlas America Public #9 Ltd. (1)
    
    Previously filed in our Form 10-KSB for
the period ending December 31, 20004
    (c)
    
    Drilling and Operating Agreement for Atlas America
Public #9 Ltd. (1)
    
    Previously filed in our Form 10-KSB for
the period ending December 31, 200023.1
    
    
    Consent of Wright and Company, Inc.31.1
    
    
    Rule 13a-14(a)/15(d)  14(a) Certification31.2
    
    
    Rule 13a-14(a)/15(d)  14(a) Certification32.1
    
    
    Section 1350 Certification32.2
    
    
    Section 1350 Certification99.1
    
    
    Section 1350 Certification
 
 (1)
    
    Filed on September 8, 2000 in the Form SB-2 Registration Statement dated September 8, 2000, File No. 333-44130  39




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SIGNATURES
   Atlas Resources, LLC, Managing General PartnerDate: March 30, 2011
    
    By:
    
    /s/ Freddie M. Kotek

Freddie M. Kotek, Chairman of the Board of Directors, Chief Executive Officerand President
  Date: March 30, 2011
    
    By:
    
    /s/ Freddie M. Kotek

Freddie M. Kotek, Chairman of the Board of Directors, Chief ExecutiveOfficer and PresidentDate: March 30, 2011
    
    By:
    
    /s/ Jeffrey C. Simmons

Jeffrey C. Simmons, Executive Vice President, OperationsDate: March 30, 2011
    
    By:
    
    /s/ Sean P. McGrath

Sean P. McGrath, Chief Financial Officer
 Supplemental information to be furnished with reports filed pursuant to Section 15(d) of the
Exchange Act by Non-reporting Issuers
   40