United
      StatesSecurities
      and Exchange CommissionWashington,
      D.C. 20549Form
      10-Q(Mark
      One)R
              QUARTERLY
      REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF
      1934For
      the quarterly period ended September 30, 2009o
              TRANSITION
      REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF
      1934For
      the transition period from _____ to _____Commission
      file number 333-127355ATLAS
      AMERICA PUBLIC #15-2005 (A) L.P.(Name
      of small business issuer in its charter)Delaware
              20-3208344(State
      or other jurisdiction of
                incorporation
      or organization)
              (I.R.S.
      Employer
                Identification
      No.)Westpointe
      Corporate Center One1550
      Coraopolis Heights Rd. 2nd FloorMoon
      Township, PA
              15108(Address
      of principal executive offices)
              (zip
      code)Issuer’s
      telephone number, including area code: (412)
      262-2830Indicate
      by check mark whether the registrant (1) has filed all reports required to
      be filed by Section 13 or 15 (d) of the SecuritiesExchange
      Act of 1934 during the preceding 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.
      YesR
      No oIndicate
      by check mark whether the registrant has submitted electronically and
      posted on its corporate Web site, if any, every
  InteractiveData
      File required to be submitted and posted pursuant to Rule 405 of
      Regulation S-T (§232.405 of this chapter) during the
    preceding12
      months (or for such shorter period that the registrant was required to
      submit and post such files). Yes o No RIndicate
      by check mark whether the registrant is a large accelerated filer, an
      accelerated filer, a non-accelerated filer or a smallerreporting
      company. See the definitions of “large accelerated filer”, “accelerated
      filer”, “non-accelerated filer” and “smaller reportingcompany”
      in Rule 12b-2 of the Exchange Act (Check One) Large accelerated filer
       ̈ Accelerated
      filer  ̈
      Non-accelerated filer  ̈Smaller
      reporting company RIndicate
      by check mark whether the registrant is a shell company (as defined in
      Rule 12b-2 of the Exchange Act). Yes o No RTransitional
      Small Business Disclosure Format (check one): Yes o No R
 
  
  
 ATLAS
AMERICA PUBLIC #15-2005 (A) L.P.
 (A
Delaware Limited Partnership)
 INDEX
TO QUARTERLY REPORT
 ON
FORM 10-Q
 
 PART
      I.
              
              FINANCIAL
      INFORMATION
              PAGEItem
      1:
              
              Financial
      StatementsBalance
      Sheets as of September 30, 2009 and December 31, 2008
              3Statements
      of Operations for the Three Months and Nine Months ended September 30,
      2009 and 2008
              4Statement
      of Changes in Partners’ Capital for the Nine Months ended September 30,
      2009
              5Statements
      of Cash Flows for the Nine Months ended September 30, 2009 and
      2008
              6Notes
      to Financial Statements
              7-18Item
      2:
              
              Management’s
      Discussion and Analysis of Financial Condition and Results of
      Operations
              19-24Item
      4:
              
              Controls
      and Procedures
              24-25PART
      II.
              
              OTHER
      INFORMATIONItem
      6:
              
              Exhibits
              25SIGNATURES
              26CERTIFICATIONS
              27-30
 
  2
  
 
 ATLAS
AMERICA PUBLIC #15-2005 (A) L.P.
 BALANCE
SHEETS
 
 September
      30,
              
              
              December
      31,2009
              
              
              2008(Unaudited)ASSETSCurrent
      assets:Cash
      and cash equivalents
              
              $
              —
              
              
              $
              464,500Accounts
      receivable-affiliate
              
              
              1,059,900
              
              
              
              1,551,800Short-term
      hedge receivable due from affiliate
              
              
              619,900
              
              
              
              1,724,600Total
      current assets
              
              
              1,679,800
              
              
              
              3,740,900Oil
      and gas properties, net
              
              
              17,566,800
              
              
              
              18,492,000Long-term
      hedge receivable due from affiliate
              
              
              434,100
              
              
              
              1,085,500$
              19,680,700
              
              
              $
              23,318,400LIABILITIES
      AND PARTNERS’ CAPITALCurrent
      liabilities:Accrued
      liabilities
              
              $
              28,300
              
              
              $
              22,200Short-term
      hedge liability due to affiliate
              
              
              9,300
              
              
              
              152,600Total
      current liabilities
              
              
              37,600
              
              
              
              174,800Asset
      retirement obligation
              
              
              1,734,100
              
              
              
              1,659,400Long-term
      hedge liability due to affiliate
              
              
              110,000
              
              
              
              137,300Partners’
      capital:Managing
      general partner
              
              
              4,429,600
              
              
              
              5,944,000Limited
      partners (5,227.40 units)
              
              
              13,694,600
              
              
              
              15,460,600Accumulated
      other comprehensive loss
              
              
              (325,200
              )
              
              
              (57,700
              )Total
      partners' capital
              
              
              17,799,000
              
              
              
              21,346,900$
              19,680,700
              
              
              $
              23,318,400
 
 
 The
accompanying notes are an integral part of these financial
statements.
  3
  
 ATLAS
AMERICA PUBLIC #15-2005 (A) L.P.
 STATEMENTS
OF OPERATIONS
 (Unaudited)
 Three
      Months Ended
                
                
                Nine
      Months EndedSeptember
      30,
                
                
                September
      30,2009
                
                
                2008
                
                
                2009
                
                
                2008REVENUESNatural
      gas and oil
                
                $
                591,600
                
                
                $
                2,016,100
                
                
                $
                2,102,900
                
                
                $
                7,114,100Interest
      income
                
                
                ―
                
                
                
                800
                
                
                
                300
                
                
                
                3,500Total
      revenues
                
                
                591,600
                
                
                
                2,016,900
                
                
                
                2,103,200
                
                
                
                7,117,600COSTS
      AND EXPENSESProduction
                
                
                364,800
                
                
                
                414,700
                
                
                
                1,102,500
                
                
                
                1,574,600Depletion
                
                
                285,500
                
                
                
                837,000
                
                
                
                925,200
                
                
                
                3,217,600Accretion
      of asset retirement obligation
                
                
                24,900
                
                
                
                21,300
                
                
                
                74,700
                
                
                
                63,800General
      and administrative
                
                
                70,300
                
                
                
                56,700
                
                
                
                184,900
                
                
                
                187,700Total
      expenses
                
                
                745,500
                
                
                
                1,329,700
                
                
                
                2,287,300
                
                
                
                5,043,700Net
      (loss) earnings
                
                $
                (153,900
                )
                
                $
                687,200
                
                
                $
                (184,100
                )
                
                $
                2,073,900Allocation
      of net (loss) earnings:Managing
      general partner
                
                $
                (14,400
                )
                
                $
                406,800
                
                
                $
                88,800
                
                
                $
                1,368,100Limited
      partners
                
                $
                (139,500
                )
                
                $
                280,400
                
                
                $
                (272‚900
                )
                
                $
                705,800Net
      (loss) earnings per limited partnership unit
                
                $
                (27
                )
                
                $
                54
                
                
                $
                (52
                )
                
                $
                135
 The
accompanying notes are an integral part of these financial
statements.
  4
  
 ATLAS
AMERICA PUBLIC #15-2005 (A) L.P.
 STATEMENT
OF CHANGES IN PARTNERS’ CAPITAL
 FOR
THE NINE MONTHS ENDED
 September
30, 2009
 (Unaudited)
 
 AccumulatedManaging
              
              
              
              
              
              OtherGeneral
              
              
              Limited
              
              
              ComprehensivePartner
              
              
              Partners
              
              
              Loss
              
              
              TotalBalance
      at January 1, 2009
              
              $
              5,944,000
              
              
              $
              15,460,600
              
              
              $
              (57,700
              )
              
              $
              21,346,900Participation
      in revenues and expenses:Net
      production revenues
              
              
              335,100
              
              
              
              665,300
              
              
              
              —
              
              
              
              1,000,400Interest
      income
              
              
              100
              
              
              
              200
              
              
              
              —
              
              
              
              300Depletion
              
              
              (159,500
              )
              
              
              (765,700
              )
              
              
              —
              
              
              
              (925,200
              )Accretion
      of asset retirement obligation
              
              
              (25,000
              )
              
              
              (49,700
              )
              
              
              —
              
              
              
              (74,700
              )General
      and administrative
              
              
              (61,900
              )
              
              
              (123,000
              )
              
              
              —
              
              
              
              (184,900
              )Net
      (loss) earnings
              
              
              88,800
              
              
              
              (272,900
              )
              
              
              —
              
              
              
              (184,100
              )Other
      comprehensive loss
              
              
              —
              
              
              
              —
              
              
              
              (267,500
              )
              
              
              (267,500
              )Working
      interest adjustment
              
              
              (517,300
              )
              
              
              517,300
              
              
              
              —
              
              
              
              —Distributions
      to partners
              
              
              (1,085,900
              )
              
              
              (2,010,400
              )
              
              
              —
              
              
              
              (3,096,300
              )Balance
      at September 30, 2009
              
              $
              4,429,600
              
              
              $
              13,694,600
              
              
              $
              (325,200
              )
              
              $
              17,799,000
 
 
 The
accompanying notes are an integral part of these financial
statements.
  5
  
 ATLAS
AMERICA PUBLIC #15-2005 (A) L.P.
 STATEMENTS
OF CASH FLOWS
 (Unaudited)
 
 Nine
      Months EndedSeptember
      30,2009
              
              
              2008Cash
      flows from operating activities:Net
      (loss) earnings
              
              $
              (184,100
              )
              
              $
              2,073,900Adjustments
      to reconcile net (loss) earnings to net cash provided by operating
      activities:Depletion
              
              
              925,200
              
              
              
              3,217,600Non-cash
      loss on derivative value
              
              
              1,318,000
              
              
              
              66,800Accretion
      of asset retirement obligation
              
              
              74,700
              
              
              
              63,800Decrease
      in accounts receivable-affiliate
              
              
              491,900
              
              
              
              542,000Increase
      (decrease) in accrued liabilities
              
              
              6,100
              
              
              
              (9,400
              )Net
      cash provided by operating activities
              
              
              2,631,800
              
              
              
              5,954,700Cash
      flows from financing activities:Distributions
      to partners
              
              
              (3,096,300
              )
              
              
              (6,093,700
              )Net
      cash used in financing activities
              
              
              (3,096,300
              )
              
              
              (6,093,700
              )Net
      decrease in cash and cash equivalents
              
              
              (464,500
              )
              
              
              (139,000
              )Cash
      and cash equivalents at beginning of period
              
              
              464,500
              
              
              
              750,600Cash
      and cash equivalents at end of period
              
              $
              —
              
              
              $
              611,600Supplemental Schedule
      of non-cash investing and financing activities:Assets
      contributed by managing general partner:Tangible
      equipment
              
              $
              —
              
              
              $
              198,300Lease
      costs
              
              
              —
              
              
              
              22,900Intangible
      drilling costs
              
              
              —
              
              
              
              763,500$
              —
              
              
              $
              984,700
 
 
 The
accompanying notes are an integral part of these financial
statements.
 
  6
  
 ATLAS
AMERICA PUBLIC #15-2005 (A) L.P.
 NOTES
TO FINANCIAL STATEMENTS
 September
30, 2009
 (Unaudited)
 
 NOTE
1 - DESCRIPTION OF BUSINESS AND BASIS OF PRESENTATION
 
 Atlas
America Public #15-2005 (A) L.P. (the “Partnership”) is a Delaware Limited
Partnership which includes Atlas Resources, LLC of Pittsburgh, Pennsylvania, as
Managing General Partner ("MGP") and Operator, and 1,636 subscribers to units as
Limited Partners. The Partnership was formed on July 25, 2005 to drill and
operate gas wells located primarily in western Pennsylvania and Tennessee. The
Partnership has no employees and relies on its MGP for management which, in
turn, relies on its parent company, Atlas Energy Resources, LLC, ("Atlas
Energy"), for administrative services. On September 29, 2009, Atlas Energy
Resources, LLC and Atlas America, Inc. (“Atlas America”) (NASDAQ: ATLS) merged
with Atlas Energy Resources, LLC becoming a wholly owned subsidiary of Atlas
America. In addition, Atlas America changed its name to “Atlas Energy,
Inc.”
 
 The
financial statements as of September 30, 2009 and for the three months and nine
months ended September 30, 2009 and 2008 are unaudited except that the balance
sheet at December 31, 2008 is derived from audited financial statements. Certain
information and footnote disclosures normally included in financial statements
prepared in accordance with accounting principles generally accepted in the
United States of America (“U.S. GAAP”) have been condensed or omitted in this
Form 10-Q pursuant to the rules and regulations of the Securities and Exchange
Commission (“SEC”). However, in the opinion of management, these interim
financial statements include all the necessary adjustments to fairly present the
results of the interim periods presented. Management has considered for
disclosure any material subsequent events through November 16, 2009, the date
the financial statements were issued. The unaudited interim financial statements
should be read in conjunction with the audited financial statements included in
the Partnership’s Form 10-K for the year ended December 31, 2008. The results of
operations for the three months and nine months ended September 30, 2009 may not
necessarily be indicative of the results of operations for the year ended
December 31, 2009.
 
 NOTE
2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
 
 In
addition to matters discussed further in this note, the Partnership’s
significant accounting policies are detailed in its audited financial statements
and notes thereto in the Partnership’s annual report on Form 10-K for the year
ended December 31, 2008 filed with the SEC.
 
 Use
of Estimates
 
 Preparation
of 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, costs and expenses
during the reporting period. The Partnership’s financial statements are based on
a number of significant estimates, including revenue and expense accruals,
depletion, fair value of derivative instruments and the probability of
forecasted transactions. Actual results could differ from these
estimates.
 
 Accounts
Receivable and Allowance for Possible Losses
 
 In
evaluating the need for an allowance for possible losses, the Partnership's MGP,
performs ongoing credit evaluations of its customers and adjusts credit limits
based upon payment history and the customer’s current creditworthiness, as
determined by review of its customers' credit information. Credit is extended on
an unsecured basis to many of its energy customers. At September 30, 2009 and
December 31, 2008, the Partnership's MGP's credit evaluation indicated that the
Partnership had no need for an allowance for possible losses.
  7
  
 ATLAS
AMERICA PUBLIC #15-2005 (A) L.P.
 NOTES
TO FINANCIAL STATEMENTS (Continued)
 September
30, 2009
 (Unaudited)
 
 NOTE
2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
 
 Revenue
Recognition
 
 The
Partnership generally sells natural gas and crude oil at prevailing market
prices.  Revenue is recognized when produced quantities are delivered
to a custody transfer point, persuasive evidence of a sales arrangement exists,
the rights and responsibility of ownership pass to the purchaser upon delivery,
collection of revenue from the sale are reasonably assured and the sales price
is fixed or determinable.  Revenues from the production of natural gas
and crude oil in which the Partnership has an interest with other producers are
recognized on the basis of the Partnership’s percentage ownership of working
interest or overriding royalty. Generally, the Partnership’s sales contracts are
based on pricing provisions that are tied to a market index, with certain
adjustments based on proximity to gathering and transmission lines and the
quality of its natural gas.
 
 Because
there are timing differences between the delivery of natural gas and oil and its
receipt of a delivery statement, the Partnership has unbilled revenues. These
revenues are accrued based upon volumetric data from the Partnership’s records
and estimates of the related transportation and compression fees which are, in
turn, based upon applicable product prices. The Partnership had unbilled trade
receivables at September 30, 2009 and December 31, 2008 of $606,900 and
$1,074,300, respectively, which are included in accounts receivable on the
Partnership’s Balance Sheets.
 
 Oil
and Gas Properties
 
 The
Partnership follows the successful-efforts method of accounting for oil and gas
producing activities. Oil and gas properties are recorded at
cost.  Depletion is determined on a field-by-field basis using the
units-of-production method for well and related equipment costs based on proved
developed reserves associated with each field. Depletion rates are determined
based on reserve quantity estimates and the capitalized costs of developed
producing properties.  In addition, accumulated depletion includes
impairment adjustments to reflect the write-down to fair market value of the oil
and gas properties. Maintenance and repairs are expensed as incurred. Major
renewals and improvements that extend the useful lives of the property are
capitalized. Oil is converted to gas equivalent basis (“Mcfe”) at the rate one
barrel equals 6 thousand cubic feet (“Mcf”).
 
 Upon the
sale or retirement of a complete field of a proved property, the cost is
eliminated from the property accounts, and the resultant gain or loss is
recorded in operations. Upon the sale or retirement of an individual well, the
net book value is credited to accumulated depletion.
 
 Oil
      and gas properties consist of the following at the dates
      indicated:
              
              September
      30,
              
              
              December
      31,2009
              
              
              2008Natural
      gas and oil properties:Proved
      properties:Leasehold
      interests
              
              $
              1,526,600
              
              
              $
              1,526,600Wells
      and related equipment
              
              
              64,310,600
              
              
              
              64,310,60065,837,200
              
              
              
              65,837,200Accumulated
      depletion
              
              
              (48,270,400
              )
              
              
              (47,345,200
              )$
              17,566,800
              
              
              $
              18,492,000
 
  8
  
 ATLAS
AMERICA PUBLIC #15-2005 (A) L.P.
 NOTES
TO FINANCIAL STATEMENTS (Continued)
 September
30, 2009
 (Unaudited)
 
 NOTE
2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
 
 Impairment
of Oil and Gas Properties and Long-Lived Assets
 
 The
Partnership’s oil and gas properties are reviewed for impairment annually or
whenever events or changes in circumstances indicate that their carrying amounts
may not be recoverable. Oil and gas properties are reviewed for potential
impairments at the lowest levels for which there are identifiable cash
flows.
 
 The
review of the Partnership’s oil and gas properties is done on a field-by-field
basis by determining if the historical cost of proved properties less the
applicable accumulated depletion and abandonment is less than the estimated
expected undiscounted future cash flows. The expected future cash flows are
estimated based on the Partnership’s plans to continue to produce and develop
proved reserves. Expected future cash flow from the sale of production of
reserves is calculated based on estimated future prices. The Partnership
estimates prices based upon current contracts in place, adjusted for basis
differentials and market related information including published futures prices.
The estimated future level of production is based on assumptions surrounding
future levels of prices and costs, field decline rates, market demand and
supply, and the economic and regulatory climates. If the carrying value exceeds
such cash flows, an impairment loss is recognized for the difference between the
estimated fair market value (as determined by discounted future cash flows), and
the carrying value of the assets.
 
 The
determination of oil and natural gas reserve estimates is a subjective process,
and the accuracy of any reserve estimate depends on the quality of available
data and the application of engineering and geological interpretation and
judgment. Estimates of economically recoverable reserves and future net cash
flows depend on a number of variable factors and assumptions that are difficult
to predict and may vary considerably from actual results. In addition, reserve
estimates for wells with limited or no production history are less reliable than
those based on actual production.  Estimated reserves are often
subject to future revisions, which could be substantial, based on the
availability of additional information which could cause the assumptions to be
modified.  The Partnership cannot predict what reserve revisions may
be required in future periods.There were no
impairments of oil and gas properties recorded by the Partnership for the three
months and nine months ended September 30, 2009 and 2008.
 
 Working
Interest
 
 The
Partnership agreement establishes that revenues and expenses will be allocated
to the MGP and limited partners based on their ratio of capital contributions to
total contributions, (“the working interest”).  The MGP is also
provided an additional working interest of 7% as provided in the Partnership
Agreement. Due to the time necessary to complete drilling operations and
accumulate all drilling costs, estimated working interest percentage ownership
rates are utilized to allocate revenues and expenses until the wells are
completely drilled and turned on-line into production. Once the wells are
completed, the final working interest ownership of the partners is determined
and any previously allocated revenues based on the estimated working interest
percentage ownership are adjusted to conform to the final working interest
percentage ownership. As of September 30, 2009 $517,300 of net earnings
resulting from the working interest adjustment was reclassified from the MGP’s
capital account to the limited partner’s capital account.
 
  9
  
 ATLAS
AMERICA PUBLIC #15-2005 (A) L.P.
 NOTES
TO FINANCIAL STATEMENTS (Continued)
 September
30, 2009
 (Unaudited)
 
 NOTE
2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
 
 Recently
Adopted Accounting Standards
 
 In August
2009, the Financial Accounting Standards Board (“FASB”) issued Accounting
Standards Update 2009-05, Fair
Value Measurements and Disclosures (Topic 820) – Measuring Liabilities at Fair
Value (“Update 2009-05”). Update 2009-05 amends subtopic 820-10, “Fair
Value Measurements and Disclosures- Overall” and provides clarification for the
fair value measurement of liabilities in circumstances where quoted prices for
an identical liability in an active market are not available. The amendments
also provide clarification for not requiring the reporting entity to include
separate inputs or adjustments to other inputs relating to the existence of a
restriction that prevents the transfer of a liability when estimating the fair
value of a liability.  Additionally, these amendments clarify that
both the quoted price in an active market for an identical liability at the
measurement date and the quoted price for an identical liability when traded as
an asset in an active market when no adjustments to the quoted price of the
asset are required are considered Level 1 fair value measurements. These
requirements are effective for financial statements issued after the release of
Update 2009-05.  The Partnership adopted the requirements on September
30, 2009 and it did not have a material impact on its financial position,
results of operations or related disclosures.
 
 In June
2009, the FASB issued Accounting Standards Update 2009-01, Topic 105- Generally Accepted
Accounting Principles Amendments Based on Statements of Financial Accounting
Standards No. 168- The FASB Accounting Standards Codification and the Hierarchy
of Generally Accepted Accounting Principles (“Update 2009-01”). Update
2009-01 establishes the FASB Accounting Standards Codification (“ASC”) as the
single source of authoritative U.S. generally accepted accounting principles
recognized by the FASB to be applied by nongovernmental entities.  The
ASC supersedes all existing non-Securities and Exchange Commission accounting
and reporting standards.  Following the ASC, the FASB will not issue
new standards in the form of Statements, FASB Staff Positions, or Emerging
Issues Task Force Abstracts. Instead, the FASB will issue Accounting Standards
Updates, which will serve only to update the ASC.  ASC 105 is
effective for financial statements issued for interim and annual periods ending
after September 15, 2009.  Entities are not required to include
specific references to the ASC in their financial statements and, therefore, the
Partnership has removed all previous references to FASB authoritative guidance
and describes its accounting policies using a “plain English” approach. The
Partnership adopted the requirements of Update 2009-01 to its financial
statements on September 30, 2009 and it did not have a material impact to the
Partnership’s financial statement disclosures.
 
 In May
2009, the FASB issued ASC 855-10, Subsequent Events (“ASC
855-10”). ASC 855-10 establishes general standards of accounting for and
disclosure of events that occur after the balance sheet date but before
financial statements are issued or are available to be issued. The provisions
require management of a reporting entity to evaluate events or transactions that
may occur after the balance sheet date for potential recognition or disclosure
in the financial statements and provides guidance for disclosures that an entity
should make about those events. ASC 855-10 is effective for interim or annual
financial periods ending after June 15, 2009 and shall be applied prospectively.
The Partnership adopted the requirements of this standard on June 30, 2009 and
it did not have a material impact to its financial position or results of
operations or related disclosures. The adoption of these provisions does not
change the Partnership’s current practices with respect to evaluating, recording
and disclosing subsequent events.
  10
  
 ATLAS
AMERICA PUBLIC #15-2005 (A) L.P.
 NOTES
TO FINANCIAL STATEMENTS (Continued)
 September
30, 2009
 (Unaudited)
 
 NOTE
2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
 
 Recently
Adopted Accounting Standards (Continued)
 
 In April
2009, the FASB issued ASC 820-10-65-4, Determining Fair Value When the
Volume and Level of Activity for the Asset or Liability Have Significantly
Decreased and Identifying Transactions That Are Not Orderly (“ASC
820-10-65-4”). ASC 820-10-65-4 applies to all fair value measurements and
provides additional clarification on estimating fair value when the market
activity for an asset has declined significantly.  ASC 820-10-65-4
also require an entity to disclose a change in valuation technique and related
inputs to the valuation calculation and to quantify its effects, if practicable.
ASC 820-10-65-4 is effective for interim and annual periods ending after June
15, 2009, with early adoption permitted for periods ending after March 15,
2009.  The Partnership adopted the requirements of ASC 820-10-65-4 on
April 1, 2009 and its adoption did not have a material impact on the
Partnership’s financial position and results of operations.
 
 In April
2009, the FASB issued ASC 825-10-65-1, Interim Disclosures about Fair Value
of Financial Instruments (“ASC 825-10-65-1”), which requires an entity to
provide disclosures about fair value of financial instruments in interim
financial information. In addition, an entity shall disclose in the body or in
the accompanying notes of its summarized financial information for interim
reporting periods and in its financial statements for annual reporting periods
the fair value of all financial instruments for which it is practicable to
estimate that value, whether recognized or not recognized in the statement of
financial position. ASC 825-10-65-1 is effective for interim periods ending
after June 15, 2009, with early adoption permitted for periods ending after
March 15, 2009.  The Partnership adopted these requirements on April
1, 2009 and its adoption did not have a material impact on the Partnership’s
financial position and results of operations.
 
 In March
2008, the FASB issued ASC 815-10-50-1, Disclosures about Derivative
Instruments and Hedging Activities (“ASC 815-10-50-1”), to require
enhanced disclosure about how and why an entity uses derivative instruments, how
derivative instruments and related hedged items are accounted for and how
derivative instruments and related hedged items affect an entity’s financial
position, financial performance and cash flows. The Partnership adopted the
requirements of this section of ASC 815-10-50-1 on January 1, 2009 and it did
not have a material impact on its financial position or results of operations
(see Note 5).
 
 Modernization
of Oil and Gas Reporting
 
 In
December 2008, the SEC announced that it had approved revisions to its oil and
gas reporting disclosures by adopting amendments to Rule 4-10 of Regulation S-X
and Items 201, 801, and 802 of Regulation S-K. These new disclosure requirements
are referred to as “Modernization of Oil and Gas Reporting” and include
provisions that:
 
 ·
              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.
  11
  
 ATLAS
AMERICA PUBLIC #15-2005 (A) L.P.
 NOTES
TO FINANCIAL STATEMENTS (Continued)
 September
30, 2009
 (Unaudited)
 
 NOTE
2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
 
 Modernization
of Oil and Gas Reporting (Continued)
 
 ·
              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 Partnership’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 Partnership’s  reserves preparer or auditor
      based on Society of Petroleum Engineers
  criteria.
 
 The
Partnership will begin complying with the disclosure requirements in its annual
report on Form 10-K for the year ending December 31, 2009. The new rules
may not be applied to disclosures in quarterly reports prior to the first annual
report in which the revised disclosures are required. The Partnership is
currently in the process of evaluating the new requirements.
 
 NOTE
3 - TRANSACTIONS WITH ATLAS RESOURCES, LLC AND ITS AFFILIATES
 
 The
Partnership has entered into the following significant transactions with its MGP
and its affiliates as provided under its Partnership agreement:
 
 ·
              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 three months and nine months
      ended September 30, 2009 were $39‚200 and $118‚300, respectively.
      Administrative costs incurred for the three months and nine months ended
      September 30, 2008 were $40,200 and $123,200,
  respectively.
 
 ·
              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 in 2009 and 2008, respectively, for operating and maintaining the
      wells. Well supervision fees incurred for the three months and nine months
      ended September 30, 2009 were $154‚900 and $467‚500, respectively. Well
      supervision fees incurred for the three months and nine months ended
      September 30, 2008 were $159,000 and $486,400,
    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 three months and nine
      months ended September 30, 2009 were $118‚900 and $407‚600, respectively.
      Transportation fees incurred for the three months and nine months ended
      September 30, 2008 were $174,100 and $842,300,
    respectively.
  12
  ATLAS
AMERICA PUBLIC #15-2005 (A) L.P.
 NOTES
TO FINANCIAL STATEMENTS (Continued)
 September
30, 2009
 (Unaudited)
 
 NOTE
3 - TRANSACTIONS WITH ATLAS RESOURCES, LLC AND ITS AFFILIATES
(Continued)
 
 ·
              Asset
      contributions from the MGP, which are disclosed on the Partnership's
      Statements of Cash Flows as a non-cash activity for the nine months ended
      September 30, 2008, was $984,700.
 
 The MGP
and its affiliates perform all administrative and management functions for the
Partnership including billing revenues and paying expenses. “Accounts
receivable-affiliate” on the Partnership's Balance Sheets represents the net
production revenues due from the MGP.
 
 Subordination
by Managing General Partner
 
 Under the
terms of the Partnership agreement, the MGP may be required to subordinate up to
50% of its share of net production revenues of the Partnership to provide a
distribution to the limited partners equal to at least 10% of their agreed
subscriptions. Subordination is determined on a cumulative basis, in each of the
first five years of Partnership operations, commencing with the first
distribution of net revenues to the investor partners (August 2006). Since
inception of the program, the MGP has not been required to subordinate any of
its distributions to its limited partners.
 
 NOTE
4 - COMPREHENSIVE (LOSS) INCOME
 
 Comprehensive
(loss) income includes net earnings and all other changes in equity of a
business during a period from transactions and other events and circumstances
from non-owner sources. These changes, other than net earnings, are referred to
as "other comprehensive (loss) income" and, for the Partnership, include changes
in the fair value of unsettled derivative contracts accounted for as cash flow
hedges. A reconciliation of the Partnership’s comprehensive (loss) income for
the periods indicated is as follows:
 
 Three
      Months Ended
              
              Nine
      Months EndedSeptember
      30,
              
              September
      30,2009
              
              2008
              
              2009
              
              
              2008Net
      (loss) earnings
              
              $
              (153,900
              )
              $
              687,200
              
              $
              (184,100
              )
              
              $
              2,073,900Other
      comprehensive (loss) income:Unrealized
      holding (losses) gains on hedging contracts
              
              
              3,800
              
              
              6,326,700
              
              
              (409,800
              )
              
              
              23,200Less:
      reclassification adjustment for losses (gains) realized in net
      earnings
              
              
              (200
              )
              
              594,500
              
              
              142,300
              
              
              
              349,600Total
      other comprehensive (loss) income
              
              
              3,600
              
              
              6,921,200
              
              
              (267,500
              )
              
              
              372,800Comprehensive
      (loss) income
              
              $
              (150,300
              )
              $
              7,608,000
              
              $
              (451,600
              )
              
              $
              2,446,700
 
  13
  
 ATLAS
AMERICA PUBLIC #15-2005 (A) L.P.
 NOTES
TO FINANCIAL STATEMENTS (Continued)
 September
30, 2009
 (Unaudited)
 
 NOTE
5 - DERIVATIVE INSTRUMENTS
 
 The
Partnership is exposed to certain risks relating to its ongoing business
operations. The risk is managed by using derivative instruments related to
commodity price risk. Forward contracts on natural gas and oil are entered into
to manage the price risk associated with forecasted sales of natural gas and
crude oil. The Partnership designates these derivatives as cash flow hedges and
the derivative instruments have been recorded as either assets or liabilities at
fair value on the balance sheets. The effective portion of the gain or loss on
the derivative is reported as a component of other comprehensive loss and
reclassified to earnings in the same period during which the hedged transaction
affects earnings. The following table summarizes the fair value of derivative
instruments as of September 30, 2009 and December 31, 2008, as well as the gain
or loss recognized for the three months and nine months ended September 30, 2009
and 2008, respectively. There were no gains or losses recognized in income for
ineffective derivative instruments for the three months and nine months ended
September 30, 2009 and 2008, respectively.
 
 Fair
      Value of Derivative Instruments:Asset
      Derivatives
              
              Liability
      DerivativesDerivatives
      in
              
              
              
              Fair
      Value
              
              
              
              Fair
      ValueCash
      Flow Hedging
              
              Balance
      Sheet
              
              September
      30,
              
              
              December
      31,
              
              Balance
      Sheet
              
              September
      30,
              
              
              December
      31,Relationships
              
              Location
              
              2009
              
              
              2008
              
              Location
              
              2009
              
              
              2008Commodity
      contracts:
              
              Current
      assets
              
              $
              619,900
              
              
              $
              1,724,600
              
              Current
      liabilities
              
              $
              (9,300
              )
              
              $
              (152,600
              )Long-term
      assets
              
              
              434,100
              
              
              
              1,085,500
              
              Long-term
      liabilities
              
              
              (110,000
              )
              
              
              (137,300
              )Total
      derivatives
              
              $
              1,054,000
              
              
              $
              2,810,100
              
              
              
              $
              (119,300
              )
              
              $
              (289,900
              )
 
 Effects
of Derivative Instruments on Statements of Operations:
 
 Derivatives
      in
              
              Gain
                Recognized
      in OCI on Derivative
                (Effective
      Portion)
                Three
      Months Ended
              
              Location
      of Gain/(Loss)
                Reclassified
      from Accumulated
              
              Gain
      (Loss)
                Reclassified
      from OCI into Income
                (Effective
      Portion)
                Three
      Months EndedCash
      Flow
              
              September
      30,
              
              
              September
      30,
              
              OCI
      into Income
              
              September
      30,
              
              
              September
      30,Hedging
      Relationship
              
              2009
              
              
              2008
              
              (Effective
      Portion)
              
              2009
              
              
              2008Commodity
      contracts
              
              $
              3,800
              
              
              $
              6,326,700
              
              Natural
      gas and oil revenue
              
              $
              200
              
              
              $
              (594,500
              )
 
 Derivatives
      in
              
              (Loss)
      Gain
                Recognized
      in OCI on Derivative
                (Effective
      Portion)
                Nine
      Months Ended
              
              Location
      of Gain/(Loss)
                Reclassified
      from Accumulated
              
              Loss
                Reclassified
      from OCI into Income
                (Effective
      Portion)
                Nine
      Months EndedCash
      Flow
              
              September
      30,
              
              
              September
      30,
              
              OCI
      into Income
              
              September
      30,
              
              
              September
      30,Hedging
      Relationship
              
              2009
              
              
              2008
              
              (Effective
      Portion)
              
              2009
              
              
              2008Commodity
      contracts
              
              $
              (409,800
              )
              
              $
              23,200
              
              Natural
      gas and oil revenue
              
              $
              (142,300
              )
              
              $
              (349,600
              )
 
 Atlas
Energy, on behalf of the Partnership, from time to time enters into natural gas
and crude oil future option contracts and collar contracts to hedge exposure to
changes in natural gas prices and oil prices. At any point in time, such
contracts may include regulated New York Mercantile Exchange (“NYMEX”) futures,
options contracts and non-regulated over-the-counter futures contracts with
qualified counterparties. NYMEX contracts are generally settled with offsetting
positions, but may be settled by the delivery of natural gas. Crude oil
contracts are based on a West Texas Intermediate ("WTI") index. These contracts
have qualified and been designated as cash flow hedges and recorded at their
fair values.
  14
  
 ATLAS
AMERICA PUBLIC #15-2005 (A) L.P.
 NOTES
TO FINANCIAL STATEMENTS (Continued)
 September
30, 2009
 (Unaudited)
 
 NOTE
5 - DERIVATIVE INSTRUMENTS (Continued)
 
 At
September 30, 2009, the Partnership reflected a net hedge asset on its Balance
Sheet of $934‚700, however unrealized gains of $1‚259‚900 which were required to
be recognized in net income which were related to impairment charges of the
Partnership’s oil and gas properties for the year ended December 31,
2008 and prior period which results in a net unrealized accumulated loss of
$325‚200. Of the remaining $325‚200 net unrealized loss in accumulated other
comprehensive loss at September 30, 2009, if the fair values of the instruments
remain at current market values, the Partnership will reclassify $102‚400 of net
losses to its Statements of Operations over the next twelve month period as
these contracts settle, and $222‚800 of net losses in later periods. Actual
amounts that will be reclassified will vary as a result of future price changes.
Ineffective hedge gains or losses are recorded within the Statements of
Operations while the hedge contract is open and may increase or decrease until
settlement of the contract. The Partnership recognized no gains or losses during
the three months and nine months ended September 30, 2009 and 2008,
respectively, for hedge ineffectiveness or as a result of the discontinuance of
cash flow hedges.
 
 As of
September 30, 2009, Atlas Energy had allocated to the Partnership the following
natural gas and oil volumes hedged:
 
 Natural
Gas Fixed Price Swaps
 Production
              
              
              
              
              AveragePeriod
      Ending
              
              Volumes
              
              
              Fixed
      Price
              
              
              Fair
      ValueDecember
      31,
              
              (MMbtu)
      (1)
              
              
              (per
      MMbtu) (1)
              
              
              Asset
      (2)2009
              
              
              77,600
              
              
              $
              8.24
              
              
              $
              271,6002010
              
              
              228,600
              
              
              
              7.71
              
              
              
              343,9002011
              
              
              139,400
              
              
              
              7.04
              
              
              
              115,3002012
              
              
              127,800
              
              
              
              7.22
              
              
              
              86,9002013
              
              
              74,500
              
              
              
              7.08
              
              
              
              10,800$
              828,500
 
 Natural
Gas Costless Collars
 Production
              
              
              
              
              
              
              Average
              
              
              Fair
      ValuePeriod
      Ending
              
              Option
              
              Volumes
              
              
              Floor
      & Cap
              
              
              AssetDecember
      31,
              
              Type
              
              (MMbtu)
      (1)
              
              
              (per
      MMbtu) (1)
              
              
              (Liability)(2)2009
              
              Puts
      purchased
              
              
              400
              
              
              $
              11.00
              
              
              $
              2,8002009
              
              Calls
      sold
              
              
              400
              
              
              
              15.35
              
              
              
              —2010
              
              Puts
      purchased
              
              
              23,800
              
              
              
              7.84
              
              
              
              43,3002010
              
              Calls
      sold
              
              
              23,800
              
              
              
              9.01
              
              
              
              —2011
              
              Puts
      purchased
              
              
              63,000
              
              
              
              6.52
              
              
              
              41,0002011
              
              Calls
      sold
              
              
              63,000
              
              
              
              7.67
              
              
              
              —2012
              
              Puts
      purchased
              
              
              24,000
              
              
              
              6.51
              
              
              
              2002012
              
              Calls
      sold
              
              
              24,000
              
              
              
              7.72
              
              
              
              —2013
              
              Puts
      purchased
              
              
              29,900
              
              
              
              6.52
              
              
              
              —2013
              
              Calls
      sold
              
              
              29,900
              
              
              
              7.81
              
              
              
              (3,000
              )$
              84,300
 
  15
  
 ATLAS
AMERICA PUBLIC #15-2005 (A) L.P.
 NOTES TO FINANCIAL STATEMENTS
(Continued)
 September
30, 2009
 (Unaudited)
 
 NOTE
5 - DERIVATIVE INSTRUMENTS (Continued)
 
 Crude
Oil Fixed Price Swaps
 Production
              
              
              
              
              AveragePeriod
      Ending
              
              Volumes
              
              
              Fixed
      Price
              
              
              Fair
      ValueDecember
      31,
              
              (Bbl)
      (1)
              
              
              (per
      Bbl) (1)
              
              
              Asset
      (3)2009
              
              
              100
              
              
              $
              99.32
              
              
              $
              2,3002010
              
              
              200
              
              
              
              97.40
              
              
              
              5,9002011
              
              
              200
              
              
              
              77.46
              
              
              
              4,0002012
              
              
              200
              
              
              
              76.86
              
              
              
              2,5002013
              
              
              50
              
              
              
              77.36
              
              
              
              700$
              15,400
 
 Crude
Oil Costless Collars
 Production
              
              
              
              
              
              
              AveragePeriod
      Ending
              
              Option
              
              Volumes
              
              
              Floor
      & Cap
              
              
              Fair
      ValueDecember
      31,
              
              Type
              
              (Bbl)
      (1)
              
              
              (per
      Bbl) (1)
              
              
              Asset
      (3)2009
              
              Puts
      purchased
              
              
              50
              
              
              $
              85.00
              
              
              $
              7002009
              
              Calls
      sold
              
              
              50
              
              
              
              116.56
              
              
              
              —2010
              
              Puts
      purchased
              
              
              200
              
              
              
              85.00
              
              
              
              2,5002010
              
              Calls
      sold
              
              
              200
              
              
              
              112.92
              
              
              
              —2011
              
              Puts
      purchased
              
              
              100
              
              
              
              67.22
              
              
              
              1,8002011
              
              Calls
      sold
              
              
              100
              
              
              
              89.44
              
              
              
              —2012
              
              Puts
      purchased
              
              
              100
              
              
              
              65.51
              
              
              
              1,2002012
              
              Calls
      sold
              
              
              100
              
              
              
              91.45
              
              
              
              —2013
              
              Puts
      purchased
              
              
              50
              
              
              
              65.36
              
              
              
              3002013
              
              Calls
      sold
              
              
              50
              
              
              
              93.44
              
              
              
              —$
              6,500Total
      Net Asset
              
              
              $
              934,700
 ______________
 
 (1)
              MMBTU
      represents million British Thermal Units. Bbl represents
      barrels.
 (2)
              Fair
      value based on forward NYMEX natural gas
prices.
 (3)
              Fair
      value based on forward WTI crude oil
prices.
 
 NOTE
6 - FAIR VALUE OF FINANCIAL INSTRUMENTS
 
 The
Partnership has established a hierarchy to measure its financial instruments at
fair value which requires it to maximize the use of observable inputs and
minimize the use of unobservable inputs when measuring fair value. The hierarchy
defines three levels of inputs that may be used to measure fair
value.
 
 Level 1–Quoted prices in
active markets for identical assets and liabilities that the reporting entity
has the ability to access at the measurement date.
  16
  
 ATLAS
AMERICA PUBLIC #15-2005 (A) L.P.
 NOTES TO FINANCIAL STATEMENTS
(Continued)
 September
30, 2009
 (Unaudited)
 
 NOTE 6 - FAIR VALUE OF FINANCIAL
INSTRUMENTS (Continued)
 
 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 entities own assumptions about the assumptions that 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
 
 The
Partnership has certain assets and liabilities that are reported at fair value
on a recurring basis in its balance sheets. The following methods and
assumptions were used to estimate fair values.
 
 All of
the Partnership’s derivatives contracts are defined as Level 2. The
Partnership's natural gas and crude oil derivative contracts are valued based on
prices quoted on the NYMEX or WTI and adjusted by the respective counterparty
using various assumptions including quoted forward prices, time value,
volatility factors, and contractual prices for the underlying instruments.
Information for assets and liabilities measured at fair value on a recurring
basis at September 30, 2009 and December 31, 2008 is as follows.
 
 September
      30, 2009
              
              
              December
      31, 2008Level
      2
              
              
              Total
              
              
              Level
      2
              
              
              TotalCommodity-based
      derivatives
              
              $
              934,700
              
              
              $
              934,700
              
              
              $
              2,520,200
              
              
              $
              2,520,200Total
              
              $
              934,700
              
              
              $
              934,700
              
              
              $
              2,520,200
              
              
              $
              2,520,200
 
 Assets
and Liabilities Measured at Fair Value on a Nonrecurring Basis
 
 The
Partnership has certain assets and liabilities that are reported at fair value
on a nonrecurring basis in its Balance Sheets. The following methods and
assumptions were used to estimate fair values.
 
 Asset Retirement
Obligations.  The Partnership estimates the fair value of asset
retirement obligations based on discounted cash flow projections using numerous
estimates, assumptions and judgments regarding such factors at the date of
establishment of an asset retirement obligation such as: amounts and timing of
settlements; the credit adjusted risk free rate of the Partnership; and
estimated inflation rates. There were no new asset retirement obligations
incurred for the three months and ninemonths ended September
30, 2009.
 
  17
  
 ATLAS
AMERICA PUBLIC #15-2005 (A) L.P.
 NOTES TO FINANCIAL STATEMENTS
(Continued)
 September
30, 2009
 (Unaudited)
 
 NOTE
7 - ASSET RETIREMENT OBLIGATION
 
 The
Partnership recognizes an estimated liability for the plugging and abandonment
of its oil and gas wells and related facilities. It also recognizes a liability
for future asset retirement obligations if a reasonable estimate of the fair
value of that liability can be made. The associated asset retirement costs are
capitalized as part of the carrying amount of the long-lived asset. The
Partnership also considers the estimated salvage value in the calculation of
depreciation, depletion and amortization.
 
 The
estimated liability is based on historical experience in plugging and abandoning
wells, estimated remaining lives of those wells based on reserve 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 creditadjusted 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
Partnership has no assets legally restricted for purposes of settling asset
retirement obligations.  Except for its oil and gas properties, the
Partnership has determined that there are no other material retirement
obligations associated with tangible long-lived assets.
 
 A
reconciliation of the Partnership’s liability for plugging and abandonment costs
for the periods indicated is as follows:
 
 Three
      Months Ended
              
              
              Nine
      Months EndedSeptember
      30,
              
              
              September
      30,2009
              
              
              2008
              
              
              2009
              
              
              2008Asset
      retirement obligation at beginning of period
              
              $
              1,709,200
              
              
              $
              1,459,500
              
              
              $
              1,659,400
              
              
              $
              1,417,000Accretion
      expense
              
              
              24,900
              
              
              
              21,300
              
              
              
              74,700
              
              
              
              63,800Asset
      retirement obligation at end of period
              
              $
              1,734,100
              
              
              $
              1,480,800
              
              
              $
              1,734,100
              
              
              $
              1,480,800
 
 NOTE
8 – COMMITMENTS AND CONTINGENCIES
 
 The
Managing General Partner is not aware of any legal proceedings filed against the
Partnership.
 
 Affiliates
of the MGP and their subsidiaries are party to various routine legal proceedings
arising in the ordinary course of their collective business. The MGP management
believes that none of these actions, individually or in the aggregate, will have
a material adverse effect on the MGP's financial condition or results of
operations.
  18
  
 ITEM
      2.
              MANAGEMENT'S
      DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION OR PLAN OF OPERATIONS
      (UNAUDITED)
 
 Forward-Looking
Statements
 
 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.
 
 Management’s
Discussion and Analysis should be read in conjunction with our Financial
Statements and the Notes to our Financial Statements.
 
 General
 
 We were
formed as a Delaware limited partnership on July 25, 2005, with Atlas Resources,
Inc. as our Managing General Partner, or MGP, to drill natural gas development
wells. Atlas Resources, Inc. was merged into a newly-formed limited liability
company, Atlas Resources LLC, which now serves as our MGP. We have no employees
and rely on our MGP for management, which, in turn, relies on its parent
company, Atlas Energy Resources, LLC (NYSE:ATN), or Atlas Energy, for
administrative services. On September 29, 2009 Atlas Energy completed its merger
with Atlas America, Inc. (NASDAQ:ATLS). In addition, Atlas America changed its
name to Atlas Energy, Inc.
 
 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
Laurel Mountain Midstream, LLC’s gas gathering system, a newly-formed
joint-venture between Atlas Energy’s affiliate, Atlas Pipeline Partners, L.P.
(NYSE:APL) and The Williams Companies (NYSE:WMB). We do not plan to sell any of
our wells and will continue to produce them until they are depleted or become
uneconomical to produce, at which time they will be plugged and abandoned or
sold.
  19
  
 Results
of Operations
 
 The
following table sets forth information relating to our production revenues,
volumes, sales prices, production costs and depletion during the periods
indicated:
 
 Three
      Months Ended
              
              
              Nine
      Months EndedSeptember
      30,
              
              
              September
      30,2009
              
              
              2008
              
              
              2009
              
              
              2008Production
      revenues (in thousands):Gas
              
              $
              551
              
              
              $
              1,962
              
              
              $
              2,041
              
              
              $
              6,904Oil
              
              
              41
              
              
              
              54
              
              
              
              62
              
              
              
              210Total
              
              $
              592
              
              
              $
              2,016
              
              
              $
              2,103
              
              
              $
              7,114Production
      volumes:Gas
      (mcf/day) (1)
              
              
              1,301
              
              
              
              2,078
              
              
              
              1,438
              
              
              
              2,673Oil
      (bbls/day) (1)
              
              
              8
              
              
              
              5
              
              
              
              5
              
              
              
              8Total
      (mcfe/day) (1)
              
              
              1,349
              
              
              
              2,108
              
              
              
              1,468
              
              
              
              2,721Average
      sales prices: (2)Gas
      (per mcf) (1)
      (3)
              
              $
              8.02
              
              
              $
              10.43
              
              
              $
              8.49
              
              
              $
              9.52Oil
      (per bbl) (1)
      (4)
              
              $
              65.47
              
              
              $
              122.76
              
              
              $
              59.01
              
              
              $
              90.37Average
      production costs:As
      a percent of revenues
              
              
              62
              %
              
              
              21
              %
              
              
              52
              %
              
              
              22
              %Per
      mcfe (1)
              
              $
              2.94
              
              
              $
              2.14
              
              
              $
              2.75
              
              
              $
              2.11Depletion
      per mcfe
              
              $
              2.30
              
              
              $
              4.32
              
              
              $
              2.30
              
              
              $
              4.31
 _____________
 
 (1)
              “Mcf”
      means thousand cubic feet, “mcfe” means thousand cubic feet equivalent and
      “bbls” means 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 $408,600 and
      $1,292,300 for the three months and nine months ended September 30, 2009,
      respectively. Previously recognized derivative gains were $31,400 and
      $66,800 for the three months and nine months ended September 30, 2008,
      respectively. The derivative gains are included in other comprehensive
      income 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 $8,000 and $25,600 for
      the three months and nine months ended September 30, 2009, respectively.
      The derivative gains are included in other comprehensive income and
      resulted from prior period impairment
charges.
 
 Natural Gas
Revenues.  Our natural gas revenues were $551,000 and
$1,962,200 for the three months ended September 30, 2009 and 2008, respectively,
a decrease of $1,411,200 (72%). The $1,411,200 decrease in natural gas revenues
for the three months ended September 30, 2009 as compared to the prior year
similar period was attributable to a $734,300 decrease in production volumes and
a $676,900 decrease in natural gas sales prices after the effect of financial
hedges, which are driven by market conditions. Our production volumes decreased
to 1,301 mcf per day for the three months ended September 30, 2009 from 2,078
mcf per day for the three months ended September 30, 2008, a decrease of 777 mcf
per day (37%). The overall decrease in natural gas production volumes for the
three months ended September 30, 2009 resulted primarily from the normal decline
inherent in the life of a well.
  20
  
 Our
natural gas revenues were $2,041,200 and $6,904,300 for the nine months ended
September 30, 2009 and 2008, respectively, a decrease of $4,863,100 (70%). The
$4,863,100 decrease in natural gas revenues for the nine months ended September
30, 2009 as compared to the prior year similar period was attributable to a
$3,203,400 decrease in production volumes and a $1,659,700 decrease in natural
gas sales prices after the effect of financial hedges, which are driven by
market conditions. Our production volumes decreased to 1,438 mcf per day for the
nine months ended September 30, 2009 from 2,673 mcf per day for the nine months
ended September 30, 2008, a decrease of 1,235 mcf per day (46%). The overall
decrease in natural gas production volumes for the nine months ended September
30, 2009 resulted primarily from the normal decline inherent in the life of a
well.
 
 Oil Revenues. We drill wells
primarily to produce natural gas, rather than oil, but some wells have limited
oil production. Our oil revenues were $40,600 and $53,900 for the three months
ended September 30, 2009 and 2008, respectively, a decrease of $13,300 (25%).
The $13,300 decrease in oil revenues for the three months ended September 30,
2009 as compared to the prior year similar period was attributable to a $50,500
decrease in oil prices, partially offset by a $37,200 increase in production
volumes. Our production volumes increased to 8 bbls per day for the three months
ended September 30, 2009 from 5 bbls per day for the three months ended
September 30, 2008, an increase of 3 bbls per day (60%).
 
 Our oil
revenues were $61,700 and $209,800 for the nine months ended September 30, 2009
and 2008, respectively, a decrease of $148,100 (71%). The $148,100 decrease in
oil revenues for the nine months ended September 30, 2009 as compared to the
prior year similar period was attributable to a $76,100 decrease in production
volumes, and a $72,000 decrease in oil prices. Our production volumes decreased
to 5 bbls per day for the nine months ended September 30, 2009 from 8 bbls per
day for the nine months ended September 30, 2008, a decrease of 3 bbls per day
(38%).
 
 Expenses.Production
expenses were $364,800 and $414,700 for the three months ended September 30,
2009 and 2008, respectively, a decrease of $49,900 (12%). Production expenses
were $1,102,500 and $1,574,600 for the nine months ended September 30, 2009 and
2008, respectively, a decrease of $472,100 (30%). These decreases were primarily
due to lower transportation and other variable expenses which are affected by a
decrease in production volumes.
 
 Depletion
of oil and gas properties as a percentage of oil and gas revenues were 48% and
42% in the three months ended September 30, 2009 and 2008, respectively; and 44%
and 45% for the nine months ended September 30, 2009 and 2008, respectively.
These percentage changes were directly attributable to changes in revenues, oil
and gas reserve quantities, product prices, production volumes and changes in
the depletable cost basis of oil and gas properties.
 
 General
and administrative expenses for the three months ended September 30, 2009 and
2008 were $70,300 and $56,700, respectively, an increase of $13,600 (24%). For
the nine months ended September 30, 2009 and 2008 these expenses were $184,900
and $187,700, respectively, a decrease of $2,800 (1%). These expenses include
third-party costs for services as well as the monthly administrative fees
charged by our MGP and vary from period to period due to the timing and billing
of the costs and services provided to the Partnership. The increase for the
three months ended September 30, 2009 was primarily due to higher third-party
costs as compared to prior year similar period.
 
 Liquidity
and Capital Resources
 
 Cash
provided by operating activities decreased $3,322,900 in the nine months ended
September 30, 2009 to $2,631,800 as compared to $5,954,700 for the nine months
ended September 30, 2008. This decrease was due to a decrease in net (loss)
earnings before depletion and accretion of $4,539,500. This was partially offset
with an increase of a net non-cash loss on derivative values of $1,251,200 and a
decrease in the change in accounts receivable-affiliate of $50,100 in the nine
months ended September 30, 2009 compared to the nine months ended September 30,
2008.
 
 Cash used
in financing activities decreased $2,997,400 during the nine months ended
September 30, 2009 to $3,096,300 from $6,093,700 for the nine months ended
September 30, 2008. This decrease was due to a decrease in cash distributions to
partners.
  21
  
 Our MGP
may withhold funds for future plugging and abandonment costs. Any additional
funds, if required, will be obtained from production revenues or borrowings from
our MGP or its affiliates, which are not contractually committed to make loans
to us. The amount that we may borrow may not at any time exceed 5% of our total
subscriptions, and we will not borrow from third-parties.
 
 The
Partnership is generally limited to the amount of funds generated by the cash
flows from our operations, which we believe is adequate to fund future
operations and distributions to our partners.  Historically, there has
been no need to borrow funds from our MGP to fund operations.
 
 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 of America. On an
on-going basis, we evaluate our estimates, including those related to our asset
retirement obligations, depletion and certain accrued receivables and
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. A
discussion of our significant accounting policies we have adopted and followed
in the preparation of our financial statements is included within “Notes to
Financial Statements” in Part I, Item 1, “Financial Statements” in this
quarterly report and in our Annual Report on Form 10-K for the year ended
December 31, 2008.
 
 Subordination
by Managing General Partner
 
 Under the
terms of the Partnership agreement, the MGP may be required to subordinate up to
50% of its share of net production revenues of the Partnership to provide a
distribution to the limited partners equal to at least 10% of their agreed
subscriptions. Subordination is determined on a cumulative basis, in each of the
first five years of Partnership operations, commencing with the first
distribution of net revenues to the investor partners (August 2006). Since
inception of the program, the MGP has not been required to subordinate any of
its distributions to its limited partners.
 
 Recently
Adopted Accounting Standards
 
 In August
2009, the Financial Accounting Standards Board or FASB issued Accounting
Standards Update 2009-05, Fair
Value Measurements and Disclosures (Topic 820) – Measuring Liabilities at Fair
Value an Update 2009-05. Update 2009-05 amends subtopic 820-10, “Fair
Value Measurements and Disclosures- Overall” and provides clarification for the
fair value measurement of liabilities in circumstances where quoted prices for
an identical liability in an active market are not available. The amendments
also provide clarification for not requiring the reporting entity to include
separate inputs or adjustments to other inputs relating to the existence of a
restriction that prevents the transfer of a liability when estimating the fair
value of a liability. Additionally, these amendments clarify that both the
quoted price in an active market for an identical liability at the measurement
date and the quoted price for an identical liability when traded as an asset in
an active market when no adjustments to the quoted price of the asset are
required are considered Level 1 fair value measurements. These requirements are
effective for financial statements issued after the release of Update 2009-05.
We adopted the requirements on September 30, 2009 and it did not have a material
impact on our financial position, results of operations or related
disclosures.
  22
  
 In June
2009, the FASB issued Accounting Standards Update 2009-01, Topic 105- Generally Accepted
Accounting Principles Amendments Based on Statements of Financial Accounting
Standards No. 168- The FASB Accounting Standards Codification and the Hierarchy
of Generally Accepted Accounting Principles an Update 2009-01. Update
2009-01 establishes the FASB Accounting Standards Codification or ASC as the
single source of authoritative U.S. generally accepted accounting principles
recognized by the FASB to be applied by nongovernmental entities. The ASC
supersedes all existing non-Securities and Exchange Commission accounting and
reporting standards.  Following the ASC, the FASB will not issue new
standards in the form of Statements, FASB Staff Positions, or Emerging Issues
Task Force Abstracts. Instead, the FASB will issue Accounting Standards Updates,
which will serve only to update the ASC. ASC 105 is effective for financial
statements issued for interim and annual periods ending after September 15,
2009. Entities are not required to include specific references to the ASC in
their financial statements and, therefore, we have removed all previous
references to FASB authoritative guidance and describes our accounting policies
using a “plain English” approach. We adopted the requirements of Update 2009-01
to our financial statements on September 30, 2009 and it did not have a material
impact to our financial statement disclosures.
 
 In May
2009, the FASB issued ASC 855-10, Subsequent Events or ASC
855-10.  ASC 855-10 establishes general standards of accounting for
and disclosure of events that occur after the balance sheet date but before
financial statements are issued or are available to be issued. The provisions
require management of a reporting entity to evaluate events or transactions that
may occur after the balance sheet date for potential recognition or disclosure
in the financial statements and provides guidance for disclosures that an entity
should make about those events. ASC 855-10 is effective for interim or annual
financial periods ending after June 15, 2009 and shall be applied
prospectively.  We adopted the requirements of this standard on June
30, 2009 and it did not have a material impact to our financial position or
results of operations or related disclosures. The adoption of these provisions
does not change our current practices with respect to evaluating, recording and
disclosing subsequent events.
 
 In April
2009, the FASB issued ASC 820-10-65-4, Determining Fair Value When the
Volume and Level of Activity for the Asset or Liability Have Significantly
Decreased and Identifying Transactions That Are Not Orderly or ASC
820-10-65-4. ASC 820-10-65-4 applies to all fair value measurements and provides
additional clarification on estimating fair value when the market activity for
an asset has declined significantly. ASC 820-10-65-4 also require an entity to
disclose a change in valuation technique and related inputs to the valuation
calculation and to quantify its effects, if practicable. ASC 820-10-65-4 is
effective for interim and annual periods ending after June 15, 2009, with early
adoption permitted for periods ending after March 15, 2009. We adopted the
requirements of ASC 820-10-65-4 on April 1, 2009 and its adoption did not have a
material impact on our financial position and results of
operations.
 
 In April
2009, the FASB issued ASC 825-10-65-1, Interim Disclosures about Fair Value
of Financial Instruments or ASC 825-10-65-1, which requires an entity to
provide disclosures about fair value of financial instruments in interim
financial information. In addition, an entity shall disclose in the body or in
the accompanying notes of its summarized financial information for interim
reporting periods and in its financial statements for annual reporting periods
the fair value of all financial instruments for which it is practicable to
estimate that value, whether recognized or not recognized in the statement of
financial position. ASC 825-10-65-1 is effective for interim periods ending
after June 15, 2009, with early adoption permitted for periods ending after
March 15, 2009.  We adopted these requirements on April 1, 2009 and
its adoption did not have a material impact on our financial position and
results of operations.
 
 In March
2008, the FASB issued ASC 815-10-50-1, Disclosures about Derivative
Instruments and Hedging Activities or ASC 815-10-50-1, to require
enhanced disclosure about how and why an entity uses derivative instruments, how
derivative instruments and related hedged items are accounted for and how
derivative instruments and related hedged items affect an entity’s financial
position, financial performance and cash flows. We adopted the requirements of
this section of ASC 815-10-50-1 on January 1, 2009 and it did not have a
material impact on our financial position or results of operations (see Note
5).
  23
  
 Modernization
of Oil and Gas Reporting
 
 In
December 2008, the Securities and Exchange Commission or SEC announced that it
had approved revisions to its oil and gas reporting disclosures by adopting
amendments to Rule 4-10 of Regulation S-X and Items 201, 801, and 802 of
Regulation S-K. These new disclosure requirements are referred to as
“Modernization of Oil and Gas Reporting” and include provisions
that:
 
 ·
              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 Partnership’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 Partnership’s reserves preparer or auditor based on
      Society of Petroleum Engineers
criteria.
 
 We will
begin complying with the disclosure requirements in its annual report on Form
10-K for the year ending December 31, 2009. The new rules may not be applied to
disclosures in quarterly reports prior to the first annual report in which the
revised disclosures are required. We are currently in the process of evaluating
the new requirements.
 
 ITEM
4.  CONTROLS AND PROCEDURES
 
 Evaluation
of Disclosure Controls and Procedures
 
 The
Partnership maintains disclosure controls and procedures that are designed to
ensure that information required to be disclosed in Securities and Exchange Act
of 1934 reports is recorded, processed, summarized and reported within the time
periods specified in the SEC’s rules and forms, and that such information is
accumulated and communicated to the MGP’s management, including the chief
executive officer and the chief financial officer, as appropriate, to allow
timely decisions regarding disclosure. In designing and evaluating the
disclosure controls and procedures, the MGP’s management recognized that any
controls and procedures, no matter how well designed and operated, can provide
only reasonable assurance of achieving the desired control objectives, and the
MGP’s management necessarily was required to apply its judgment in evaluating
the cost-benefit relationship of possible controls and procedures.
 
 Under the
supervision of the chief executive officer and chief financial officer, the MGP
has carried out an evaluation of the effectiveness of the Partnership’s
disclosure controls and procedures as of the end of the period covered by this
report. Based upon that evaluation, the chief executive officer and chief
financial officer concluded that the Partnership’s disclosure controls and
procedures are effective at the reasonable assurance level at September 30,
2009.
  24
  
 There
have been no changes in the Partnership’s internal control over financial
reporting during our most recent fiscal quarter that have materially affected,
or are reasonably likely to materially effect, our internal control over
financial reporting.
 
 PART
II.  OTHER INFORMATION
 
 ITEM
6.  EXHIBITS
 EXHIBIT
INDEX
 
 Exhibit
      No.
              
              Description4.0
              
              Amended
      and Restated Certificate and Agreement of Limited Partnership for Public
      #15-2005 (A) L.P. (1)10.1
              
              Drilling
      and Operating Agreement for Atlas America Public #15-2005 (A) L.P. (1)31.1
              
              Certification
      Pursuant to Rule 13a-14/15(d)-1431.2
              
              Certification
      Pursuant to Rule 13a-14/15(d)-1432.1
              
              Certification
      Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of
      the Sarbanes-OxleyAct
      of 200232.2
              
              Certification
      Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of
      the Sarbanes-OxleyAct
      of 2002
 ____________
 
 (1)
              
              Filed
      on August 9, 2005 in the Form S-1 Registration Statement dated August 9,
      2005, File No. 333-127355
 
  25
  
 SIGNATURES
 
 In
      accordance with Section 13 or 15(d) of the Exchange Act, the registrant
      caused this report to be signed on itsbehalf
      by the undersigned, thereunto duly authorized.Atlas
      America Public #15-2005 (A) L.P.Date:  November
      16, 2009
              
              Atlas
      Resources, LLC, Managing General PartnerBy: /s/ Freddie M.
      KotekFreddie
      M. Kotek, Chairman of the Board of Directors, Chief
    ExecutiveOfficer
      and PresidentIn
      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.Date:  November
      16, 2009
              
              By:/s/ Freddie M.
      KotekFreddie
      M. Kotek, Chairman of the Board of Directors, Chief
    ExecutiveOfficer
      and PresidentDate:  November
      16, 2009
              
              By:/s/ Matthew A.
      JonesMatthew
      A. Jones, Chief Financial OfficerDate:  November
      16, 2009
              
              By:/s/ Sean P.
      McGrathSean
      P. McGrath, Chief Accounting Officer
 
 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.
  26