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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 000-51944
 ATLAS AMERICA PUBLIC #15-2005 (A) L.P.
  Delaware
(State or other jurisdiction of 
incorporation or organization)
    
    20-3208344
(I.R.S. Employer
Identification No.)
 Westpointe Corporate Center One 
1550 Coraopolis Heights Rd. 2nd FloorMoon Township, PA
(Address of principal executive offices)
    
    15108
(zip code)
 (412) 262-2830
  Title of each class 
None
    
    Name of each exchange on which registered
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
 DOCUMENTS INCORPORATED BY REFERENCE: None




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##### 



ATLAS AMERICA PUBLIC #15-2005 (A) L.P.
(A DELAWARE LIMITED PARTNERSHIP)
INDEX TO ANNUAL REPORT
ON FORM 10-K
 PAGEPART IItem 1: Business
    
    
    3-5Item 2: Properties
    
    
    5-9Item 3: Legal Proceedings
    
    
    10Item 4: (Removed and Reserved)
    
    
    10PART 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
    
    
    11-15Item 8: Financial Statements
    
    
    16-35Item 9: Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
    
    
    36Item 9A: Controls and Procedures
    
    
    36Item 9B: Other Information
    
    
    37PART IIIItem 10: Directors and Executive Officers of the Registrant
    
    
    37-38Item 11: Executive Compensation
    
    
    38Item 12: Security Ownership of Certain Beneficial Owners and Management
    
    
    39Item 13: Certain Relationships and Related Party Transactions
    
    
    39Item 14: Principal Accountant Fees and Services
    
    
    39PART IVItem 15: Exhibits
    
    
    40SIGNATURES
    
    
    41Exhibit 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 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;
 
    
    restriction 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.
  
 
 ITEM 2.
    
    PROPERTIES
 Drilling Activity .
 Summary of Producing Wells .
 Number of Producing WellsGross
    
    
    NetGas
    
    
    187
    
    
    
    181.50
  5




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##### Table of Contents



Production.
 AverageYear
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    Production CostEnded
    
    Production
    
    
    Average Sales Price
    
    
    (Lifting Cost)December 31,
    
    Oil (bbls) (1)
    
    
    Gas (mcf) (1)
    
    
    per bbl (1) (3) (5)
    
    
    per mcf (1) (3) (4)
    
    
    per mcfe (1) (2)2010
    
    
    1,600
    
    
    
    440,000
    
    
    $
    73.58
    
    
    $
    6.80
    
    
    $
    2.902009
    
    
    2,000
    
    
    
    529,400
    
    
    $
    61.33
    
    
    $
    7.82
    
    
    $
    2.74
 
 (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, insurance and gathering
charges.(3)
    
    Average sales prices represent accrual basis pricing after reversing the effect
of previously recognized gains resulting from prior period impairment charges.(4)
    
    Average gas prices are calculated by including in total revenue derivative gains
previously recognized into income and dividing by the total volume for the period.
Previously recognized derivative gains were $475,600 and $1,595,300 for the years ended
December 31, 2010 and 2009, respectively. The derivative gains are included in other
comprehensive income (loss) and resulted from prior period impairment charges.(5)
    
    Average oil prices are calculated by including in total revenue derivative gains
previously recognized into income and dividing by the total volume for the period.
Previously recognized derivative gains were $17,800 and $31,200 for the years ended
December 31, 2010 and 2009, respectively. The derivative gains are included in other
comprehensive income (loss) and resulted from prior period impairment 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)
    
    
    2,356,700
    
    
    
    2,902,700Oil reserves  proved developed reserves (Bbl) (1) (2) (4)
    
    
    9,300
    
    
    
    9,600Total proved reserves (Mcfe)
    
    
    2,412,500
    
    
    
    2,960,300PV-10 estimate of cash flows of proved reserves (3) (4)
    
    $
    3,097,200
    
    
    $
    3,604,200PV-10 estimate per limited partner unit (5)
    
    $
    394
    
    
    $
    459Undiscounted estimate per limited partner unit (5)
    
    $
    566
    
    
    $
    669
 
 (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
only by contractual arrangements, but not on escalations based upon 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
   8




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Acreage.
 Developed AcreageLocation
    
    Gross (1)
    
    
    Net (2)Pennsylvania
    
    
    3,766.47
    
    
    
    3,713.10Tennessee
    
    
    800.00
    
    
    
    740.00Total
    
    
    4,566.47
    
    
    
    4,453.10
 
 (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 0.5 net acre. Delivery Commitments
     9




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ITEM 3.
    
    LEGAL PROCEEDINGS
   
 ITEM 4.
    
    (REMOVED AND RESERVED)
  
 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.
   
    
    $1,516,300 and $2,829,500 to our limited partners; and
 
    
    $375,400 and $849,300 to our managing general partner, respectively.
  10




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ITEM 7.
    
    MANAGEMENTS DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION OR PLAN
OF OPERATIONS
     11




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Results of Operations.
 Years Ended December 31,2010
    
    
    2009Production revenues (in thousands):Gas
    
    $
    2,516
    
    
    $
    2,544Oil
    
    
    99
    
    
    
    92Total
    
    $
    2,615
    
    
    $
    2,636Production volumes:Gas (mcf/day) (1)
    
    
    1,206
    
    
    
    1,450Oil (bbls/day) (1)
    
    
    4
    
    
    
    5Total (mcfe/day) (1)
    
    
    1,230
    
    
    
    1,480Average sales prices: (2)Gas (per mcf) (1) (3)
    
    $
    6.80
    
    
    $
    7.82Oil (per bbl) (1) (4)
    
    $
    73.58
    
    
    $
    61.33Average production costs:As a percent of revenues
    
    
    50
    %
    
    
    56
    %Per mcfe (1)
    
    $
    2.90
    
    
    $
    2.74Depletion per mcfe
    
    $
    4.84
    
    
    $
    2.93
 
 (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.(2)
    
    Average sales prices represent accrual basis pricing after reversing the effect
of previously recognized gains resulting from prior period impairment charges.(3)
    
    Average gas prices are calculated by including in total revenue derivative gains
previously recognized into income and dividing by the total volume for the period.
Previously recognized derivative gains were $475,600 and $1,595,300 for the years ended
December 31, 2010 and 2009, respectively. The derivative gains are included in other
comprehensive income (loss) and resulted from prior period impairment charges.(4)
    
    Average oil prices are calculated by including in total revenue derivative gains
previously recognized into income and dividing by the total volume for the period.
Previously recognized derivative gains were $17,800 and $31,200 for the years ended
December 31, 2010 and 2009, respectively. The derivative gains are included in other
comprehensive income (loss) and resulted from prior period impairment charges. Natural Gas Revenues .
   12




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Oil Revenues .
 Expenses.
    Liquidity and Capital Resources .
     13




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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
    14




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Reserve Estimates .
 Asset Retirement Obligations .
 Working Interest .
  15




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ITEM 8.
    
    FINANCIAL STATEMENTS
 REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
 
     
  16




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ATLAS AMERICA PUBLIC #15-2005 (A) L.P.
BALANCE SHEETS
DECEMBER 31,
 2010
    
    
    2009ASSETSCurrent assets:Cash and cash equivalents
    
    $
    115,500
    
    
    $
    161,500Accounts receivable-affiliate
    
    
    471,400
    
    
    
    754,000Short-term hedge receivable due from affiliate
    
    
    466,800
    
    
    
    508,000Total current assets
    
    
    1,053,700
    
    
    
    1,423,500Oil and gas properties, net
    
    
    6,913,400
    
    
    
    17,108,600Long-term hedge receivable due from affiliate
    
    
    456,300
    
    
    
    417,700$
    8,423,400
    
    
    $
    18,949,800LIABILITIES AND PARTNERS CAPITALCurrent liabilities:Accrued liabilities
    
    $
    13,500
    
    
    $
    60,200Short-term hedge liability due to affiliate
    
    
    4,600
    
    
    
    6,100Total current liabilities
    
    
    18,100
    
    
    
    66,300Asset retirement obligations
    
    
    2,635,900
    
    
    
    1,961,000Long-term hedge liability due to affiliate
    
    
    80,800
    
    
    
    64,400Partners capital:Managing general partner
    
    
    2,392,500
    
    
    
    4,575,900Limited partners (5,227.40 units)
    
    
    3,207,800
    
    
    
    12,378,400Accumulated other comprehensive income (loss)
    
    
    88,300
    
    
    
    (96,200
    )Total partners capital
    
    
    5,688,600
    
    
    
    16,858,100$
    8,423,400
    
    
    $
    18,949,800
   17




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ATLAS AMERICA PUBLIC #15-2005 (A) L.P.
STATEMENTS OF OPERATIONS
YEARS ENDED DECEMBER 31, 2010 AND 2009
 2010
    
    
    2009REVENUESNatural gas and oil
    
    $
    2,615,300
    
    
    $
    2,635,500Interest income
    
    
    200
    
    
    
    400Total revenues
    
    
    2,615,500
    
    
    
    2,635,900COST AND EXPENSESProduction
    
    
    1,305,700
    
    
    
    1,480,800Depletion
    
    
    2,174,100
    
    
    
    1,585,400Impairment of oil and gas properties
    
    
    8,286,900
    
    
    
    Accretion of asset retirement obligations
    
    
    117,700
    
    
    
    99,600General and administrative
    
    
    193,400
    
    
    
    241,600Total expenses
    
    
    12,077,800
    
    
    
    3,407,400Net loss
    
    $
    (9,462,300
    )
    
    $
    (771,500
    )Allocation of net loss:Managing general partner
    
    $
    (1,510,500
    )
    
    $
    (1,500
    )Limited partners
    
    $
    (7,951,800
    )
    
    $
    (770,000
    )Net loss per limited partnership unit
    
    $
    (1,521
    )
    
    $
    (147
    )
   18




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ATLAS AMERICA PUBLIC #15-2005 (A) L.P.
STATEMENTS OF COMPREHENSIVE LOSS
YEARS ENDED DECEMBER 31, 2010 AND 2009
 2010
    
    
    2009Net loss
    
    $
    (9,462,300
    )
    
    $
    (771,500
    )Other comprehensive income (loss):Unrealized holding gains (loss) on hedging contracts
    
    
    560,700
    
    
    
    (101,200
    )Less: reclassification adjustment for (gains) losses realized in net earnings
    
    
    (376,200
    )
    
    
    62,700Total other comprehensive income (loss)
    
    
    184,500
    
    
    
    (38,500
    )Comprehensive loss
    
    $
    (9,277,800
    )
    
    $
    (810,000
    )
   19




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ATLAS AMERICA PUBLIC #15-2005 (A) L.P.
STATEMENTS OF CHANGES IN PARTNERS CAPITAL
YEARS ENDED DECEMBER 31, 2010 AND 2009
 AccumulatedManaging
    
    
    
    
    
    
    OtherGeneral
    
    
    Limited
    
    
    ComprehensivePartner
    
    
    Partners
    
    
    (Loss) Income
    
    
    TotalBalance at December 31, 2008
    
    $
    5,944,000
    
    
    $
    15,460,600
    
    
    $
    (57,700
    )
    
    $
    21,346,900Participation in revenue and expenses:Net production revenues
    
    
    386,800
    
    
    
    767,900
    
    
    
    
    
    
    
    1,154,700Interest income
    
    
    100
    
    
    
    300
    
    
    
    
    
    
    
    400Depletion
    
    
    (274,100
    )
    
    
    (1,311,300
    )
    
    
    
    
    
    
    (1,585,400
    )Accretion of asset retirement obligations
    
    
    (33,400
    )
    
    
    (66,200
    )
    
    
    
    
    
    
    (99,600
    )General and administrative
    
    
    (80,900
    )
    
    
    (160,700
    )
    
    
    
    
    
    
    (241,600
    )Net loss
    
    
    (1,500
    )
    
    
    (770,000
    )
    
    
    
    
    
    
    (771,500
    )Other comprehensive loss
    
    
    
    
    
    
    
    
    
    
    (38,500
    )
    
    
    (38,500
    )Working interest adjustment
    
    
    (517,300
    )
    
    
    517,300
    
    
    
    
    
    
    
    Distributions to partners
    
    
    (849,300
    )
    
    
    (2,829,500
    )
    
    
    
    
    
    
    (3,678,800
    )Balance at December 31, 2009
    
    $
    4,575,900
    
    
    $
    12,378,400
    
    
    $
    (96,200
    )
    
    $
    16,858,100Participation in revenue and expenses:Net production revenues
    
    
    438,700
    
    
    
    870,900
    
    
    
    
    
    
    
    1,309,600Interest income
    
    
    100
    
    
    
    100
    
    
    
    
    
    
    
    200Depletion
    
    
    (383,500
    )
    
    
    (1,790,600
    )
    
    
    
    
    
    
    (2,174,100
    )Impairment of oil and gas properties
    
    
    (1,461,600
    )
    
    
    (6,825,300
    )
    
    
    
    
    
    
    (8,286,900
    )Accretion of asset retirement obligations
    
    
    (39,400
    )
    
    
    (78,300
    )
    
    
    
    
    
    
    (117,700
    )General and administrative
    
    
    (64,800
    )
    
    
    (128,600
    )
    
    
    
    
    
    
    (193,400
    )Net loss
    
    
    (1,510,500
    )
    
    
    (7,951,800
    )
    
    
    
    
    
    
    (9,462,300
    )Other comprehensive income
    
    
    
    
    
    
    
    
    
    
    184,500
    
    
    
    184,500Subordination
    
    
    (297,500
    )
    
    
    297,500
    
    
    
    
    
    
    
    Distributions to partners
    
    
    (375,400
    )
    
    
    (1,516,300
    )
    
    
    
    
    
    
    (1,891,700
    )Balance at December 31, 2010
    
    $
    2,392,500
    
    
    $
    3,207,800
    
    
    $
    88,300
    
    
    $
    5,688,600
   20




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ATLAS AMERICA PUBLIC #15-2005 (A) L.P.
STATEMENTS OF CASH FLOWS
YEARS ENDED DECEMBER 31, 2010 AND 2009
 2010
    
    
    2009Cash flows from operating activities:Net loss
    
    $
    (9,462,300
    )
    
    $
    (771,500
    )Adjustments to reconcile net loss to net cash provided by operating activities:Depletion
    
    
    2,174,100
    
    
    
    1,585,400Non-cash loss on derivative
    
    
    202,000
    
    
    
    1,626,500Impairment of oil and gas properties
    
    
    8,578,300
    
    
    
    Accretion of asset retirement obligation
    
    
    117,700
    
    
    
    99,600(Decrease) increase in accrued liabilities
    
    
    (46,700
    )
    
    
    38,000Decrease in accounts receivable-affiliate
    
    
    282,600
    
    
    
    797,800Net cash provided by operating activities
    
    
    1,845,700
    
    
    
    3,375,800Cash flows from financing activities:Distributions to partners
    
    
    (1,891,700
    )
    
    
    (3,678,800
    )Net cash used in financing activities
    
    
    (1,891,700
    )
    
    
    (3,678,800
    )Net decrease in cash and cash equivalents
    
    
    (46,000
    )
    
    
    (303,000
    )Cash and cash equivalents at beginning of period
    
    
    161,500
    
    
    
    464,500Cash and cash equivalents at end of period
    
    $
    115,500
    
    
    $
    161,500Supplemental Schedule of non-cash investing and financing activities:Asset retirement obligation revision
    
    $
    557,200
    
    
    $
    202,000
   21




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ATLAS AMERICA PUBLIC #15-2005 (A) L.P.
NOTES TO FINANCIAL STATEMENTS
DECEMBER 31, 2010 AND 2009
 NOTE 1  DESCRIPTION OF BUSINESS
   NOTE 2  SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
  Use of Estimates
   Account Receivable and Allowance for Possible Losses
   22




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ATLAS AMERICA PUBLIC #15-2005 (A) L.P.
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
   23




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ATLAS AMERICA PUBLIC #15-2005 (A) L.P.
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
   24




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ATLAS AMERICA PUBLIC #15-2005 (A) L.P.
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 Loss
   25




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ATLAS AMERICA PUBLIC #15-2005 (A) L.P.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2010 AND 2009
 NOTE 2  SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
 Recently Adopted Accounting Standards
     26




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ATLAS AMERICA PUBLIC #15-2005 (A) L.P.
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)
    
    
    33.50
    %
    
    
    66.50
    %Operating costs, administrative costs, direct and all other costs (2)
    
    
    33.50
    %
    
    
    66.50
    %Intangible drilling costs
    
    
    1.29
    %
    
    
    98.71
    %Tangible equipment costs
    
    
    66.26
    %
    
    
    33.74
    %
 
 (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 and the MGP revenue percentage may not exceed 40%.(2)
    
    These costs will be charged to the partners in the same ratio as the related
production revenues are credited.  27




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ATLAS AMERICA PUBLIC #15-2005 (A) L.P.
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
    
    $
    1,526,600
    
    
    $
    1,526,600Wells and related equipment
    
    
    65,069,800
    
    
    
    64,512,60066,596,400
    
    
    
    66,039,200Accumulated depletion
    
    
    (59,683,000
    )
    
    
    (48,930,600
    )$
    6,913,400
    
    
    $
    17,108,600
 NOTE 5  ASSET RETIREMENT OBLIGATIONS
    Years Ended December 31,2010
    
    
    2009Asset retirement obligation at beginning of year
    
    $
    1,961,000
    
    
    $
    1,659,400Revisions in estimates
    
    
    557,200
    
    
    
    202,000Accretion expense
    
    
    117,700
    
    
    
    99,600Asset retirement obligation at end of year
    
    $
    2,635,900
    
    
    $
    1,961,000
  28




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ATLAS AMERICA PUBLIC #15-2005 (A) L.P.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2010 AND 2009
 NOTE 6  DERIVATIVE INSTRUMENTS
     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
    
    $
    466,800
    
    
    $
    508,000
    
    
    Current liabilities
    
    $
    (4,600
    )
    
    $
    (6,100
    )Long-Term Assets
    
    
    456,300
    
    
    
    417,700
    
    
    Long-term liabilities
    
    
    (80,800
    )
    
    
    (64,400
    )Total Derivatives
    
    
    
    
    
    $
    923,100
    
    
    $
    925,700
    
    
    
    
    
    
    $
    (85,400
    )
    
    $
    (70,500
    )
  29




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ATLAS AMERICA PUBLIC #15-2005 (A) L.P.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2010 AND 2009
 NOTE 6  DERIVATIVE INSTRUMENTS (Continued)
 Effects of Derivative Instruments on Statement of Operations:
 Gain (Loss)
    
    
    
    
    
    
    Gain (Loss)Recognized in OCI on Derivative
    
    
    
    
    
    
    Reclassified from OCI into Net Loss(Effective Portion)
    
    
    Location of Gain
    
    
    (Effective Portion)Derivatives in
    
    Twelve Months Ended
    
    
    Reclassified from Accumulated
    
    
    Twelve Months EndedCash Flow
    
    December 31,
    
    
    December 31,
    
    
    OCI into (Loss) Income
    
    
    December 31,
    
    
    December 31,Hedging Relationships
    
    2010
    
    
    2009
    
    
    (Effective Portion)
    
    
    2010
    
    
    2009Commodity Contracts
    
    $
    560,700
    
    
    $
    (101,200
    )
    
    Natural Gas and Oil Revenue
    
    $
    376,200
    
    
    $
    (62,700
    )
    Natural Gas Fixed Price Swaps
 Production
    
    
    
    
    
    AveragePeriod Ending
    
    Volumes
    
    
    Fixed Price
    
    
    Fair ValueDecember 31,
    
    (MMbtu) (1)
    
    
    (per MMbtu) (1)
    
    
    Asset (2)2011
    
    
    134,300
    
    
    $
    6.964
    
    
    $
    328,9002012
    
    
    75,500
    
    
    
    7.485
    
    
    
    180,4002013
    
    
    49,000
    
    
    
    6.803
    
    
    
    68,0002014
    
    
    22,900
    
    
    
    5.942
    
    
    
    9,100$
    586,400
  30




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ATLAS AMERICA PUBLIC #15-2005 (A) L.P.
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
    
    
    65,700
    
    
    $
    6.535
    
    
    $
    137,1002011
    
    Calls sold
    
    
    65,700
    
    
    
    7.653
    
    
    
    (1,700
    )2012
    
    Puts purchased
    
    
    40,500
    
    
    
    6.102
    
    
    
    60,9002012
    
    Calls sold
    
    
    40,500
    
    
    
    7.328
    
    
    
    (10,300
    )2013
    
    Puts purchased
    
    
    68,700
    
    
    
    5.862
    
    
    
    99,2002013
    
    Calls sold
    
    
    68,700
    
    
    
    7.043
    
    
    
    (43,700
    )2014
    
    Puts purchased
    
    
    23,800
    
    
    
    5.705
    
    
    
    33,8002014
    
    Calls sold
    
    
    23,800
    
    
    
    6.811
    
    
    
    (22,300
    )$
    253,000
 Crude Oil Fixed Price Swaps
 Production
    
    
    
    
    
    AveragePeriod Ending
    
    Volumes
    
    
    Fixed Price
    
    
    Fair ValueDecember 31,
    
    (Bbl) (1)
    
    
    (per Bbl) (1)
    
    
    Liability (3)2011
    
    
    200
    
    
    $
    87.703
    
    
    $
    (1,400
    )2012
    
    
    200
    
    
    
    87.299
    
    
    
    (1,200
    )2013
    
    
    100
    
    
    
    87.632
    
    
    
    (300
    )2014
    
    
    
    
    
    
    
    
    
    
    $
    (2,900
    )
 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
    
    
    200
    
    
    $
    76.818
    
    
    $
    3002011
    
    Calls sold
    
    
    200
    
    
    
    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
    
    $
    835,200
 
 (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.  31




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ATLAS AMERICA PUBLIC #15-2005 (A) L.P.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2010 AND 2009
 NOTE 7  FAIR VALUE OF FINANCIAL INSTRUMENTS
  Level 1
    
    Unadjusted quoted prices in active markets for identical unrestricted assets
and liabilities that the reporting entity has the ability to access at the measurement
date.
 Level 2
    
    Inputs other than quoted prices included within Level 1 that are observable
for the asset and liability or can be corroborated with observable market data for
substantially the entire contractual term of the asset or liability.
 Level 3
    
    Unobservable inputs that reflect the entitys own assumptions about the
assumptions market participants would use in the pricing of the asset or liability and
are consequently not based on market activity, but rather through particular valuation
techniques.
 Assets and Liabilities Measured at Fair Value on a Recurring Basis
  Assets and Liabilities Measured at Fair Value on a Non-Recurring Basis
  NOTE 8  CERTAIN RELATIONSHIPS AND RELATED 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.
Administrative costs incurred for the years ended December 31, 2010 and 2009 were $152,100
and $157,600, respectively.
  32




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ATLAS AMERICA PUBLIC #15-2005 (A) L.P.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2010 AND 2009
 NOTE 8  CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS (Continued)
 
    
    Monthly well supervision fees which are included in production expenses in the
Partnerships statements of operations are payable at $296 per well per month for operating
and maintaining the wells. Well supervision fees incurred for the years ended December 31,
2010 and 2009 were $601,000 and $622,900, 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 $378,500
and $512,600, 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 $367,500 and $429,300, respectively.
  Subordination by Managing General Partner
  NOTE 9  COMMITMENTS AND CONTINGENCIES
   Legal Proceedings
    33




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ATLAS AMERICA PUBLIC #15-2005 (A) L.P.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2010 AND 2009
 NOTE 10  NATURAL GAS AND OIL PRODUCING ACTIVITIES (UNAUDITED)
 (1) Capitalized Costs Related to Oil and Gas Producing Activities
  December 31,2010
    
    
    2009Leasehold interest:
    
    $
    1,526,600
    
    
    $
    1,526,600Wells and related equipment
    
    
    65,069,800
    
    
    
    64,512,600Accumulated depletion
    
    
    (59,683,000
    )
    
    
    (48,930,600
    )Net capitalized cost
    
    $
    6,913,400
    
    
    $
    17,108,600
 (2) Oil and Gas Reserve Information
     34




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ATLAS AMERICA PUBLIC #15-2005 (A) L.P.
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
    
    
    6,601,900
    
    
    
    12,300Production
    
    
    (529,400
    )
    
    
    (2,000
    )Revisions to previous estimates
    
    
    (3,169,800
    )
    
    
    (700
    )Balance at December 31, 2009
    
    
    2,902,700
    
    
    
    9,600Production
    
    
    (440,000
    )
    
    
    (1,600
    )Revisions to previous estimates
    
    
    (106,000
    )
    
    
    1,300Balance at December 31, 2010
    
    
    2,356,700
    
    
    
    9,300
 NOTE 11  SUBSEQUENT EVENTS
 Atlas Energy, Inc. Asset Acquisition
  Laurel Mountain Sale
  Hedge Monetization
   35




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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
     36




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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 America 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.
 Freddie M. Kotek
  37




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##### Table of Contents



Jeffrey C. Simmons.
 Jack L. Hollander.
 Sean P. McGrath
 Audit Committee Financial Expert.
 Remuneration of Officers and Directors.
 Code of Business Conduct and Ethics. nd
 
 ITEM 11.
    
    EXECUTIVE COMPENSATION
   38




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##### Table of Contents



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.
 
 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.
  39




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PART IV
 
 ITEM 15.
    
    EXHIBITS
 
 EXHIBIT INDEX
 Description
    
    Location4
    (a)
    
    Certificate of Limited Partnership for Atlas America Public #15-2005 (A) L.P.
    
    Previously filed in our Form S-1 on August 9, 20054
    (b)
    
    Amended and Restated Certificate and Agreement of Limited Partnership for Atlas America Public #15-2005 (A) L.P. (1)
    
    Previously filed in our Form S-1 on August 9, 20054
    (c)
    
    Drilling and Operating Agreement for Atlas America Public #15-2005 (A) L.P. (1)
    
    Previously filed in our Form S-1 on August 9, 200523.1
    
    
    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) Certification.32.1
    
    
    Section 1350 Certification.32.2
    
    
    Section 1350 Certification.99.1
    
    
    Summary Reserve Report
 
 (1)
    
    Filed on August 9, 2005 in the Form S-1 Registration Statement dated August 9, 2005, File No. 333-127355  40




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SIGNATURES
   Atlas Resources, LLC, Managing General PartnerDate:  March 30, 2011
    By:
    /s/ Freddie M. KotekFreddie M. Kotek,
 Chairman of the Board of Directors,
 Chief Executive Officer and President  Date:  March 30, 2011
    By:
    /s/ Freddie M. KotekFreddie M. Kotek, 
Chairman of the Board of Directors,
 Chief Executive Officer and PresidentDate:  March 30, 2011
    By:
    /s/ Jeffrey C. SimmonsJeffrey C. Simmons, Executive Vice President  OperationsDate:  March 30, 2011
    By:
    /s/ Sean P. McGrathSean 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
   41