##### Table of Contents



United States
Securities and Exchange Commission
 Washington, D.C. 20549
 Form 10-K
  þ
    
    ANNUAL REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934
 For the fiscal year ended December 31, 2009
 o
    
    TRANSITION REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934
 For the transition period from  to
 Commission file number 333-150925-03
 ATLAS RESOURCES PUBLIC 18-2008 (A) L.P.
  Delaware
(State or other jurisdiction of 
Incorporation or organization)
    
    26-2202544
(I.R.S. Employer
Identification No.)Westpointe Corporate Center One 
1550 Coraopolis Heights Road, 2nd Floor 
Moon Township, PA
(Address of principal executive offices)
    
    15108
(Zip Code)
 (412) 262-2830
  Title of each class
    
    Name of each exchange on which registeredNone
    
    None
 
 Yes o No þ
 Yes o No þ
 Yes þ No o
 þ
  Large accelerated filer o
    
    Accelerated filer o
    
    Non-accelerated filer o
    
    Smaller reporting company þ
 Yes o No þ




---



##### 



ATLAS RESOURCES PUBLIC 18-2008 (A) L.P.
(A DELAWARE LIMITED PARTNERSHIP)
INDEX TO ANNUAL REPORT
ON FORM 10-K
 PAGEPART IItem 1: Business
    
    
    3-5Item 2: Properties
    
    
    5-9Item 3: Legal Proceedings
    
    
    10Item 4: (Removed and Reserved)
    
    
    10PART IIItem 5: Market for Registrants Common Equity and Related Security Holder Matters
    
    
    10Item 7: Managements Discussion and Analysis of Financial Condition or Plan of Operations
    
    
    11-14Item 8: Financial Statements
    
    
    15-35Item 9: Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
    
    
    35Item 9A: Controls and Procedures
    
    
    35-36Item 9B: Other Information
    
    
    36PART IIIItem 10: Directors and Executive Officers of the Registrant
    
    
    36-38Item 11: Executive Compensation
    
    
    39Item 12: Security Ownership of Certain Beneficial Owners and Management
    
    
    39Item 13: Certain Relationships and Related Party Transactions
    
    
    39-40Item 14: Principal Accountant Fees and Services
    
    
    40PART IVItem 15: Exhibits
    
    
    41SIGNATURES
    
    
    42Exhibit 23.1Exhibit 31.1Exhibit 31.2Exhibit 32.1Exhibit 32.2Exhibit 99.1
   2




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




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##### Table of Contents



Markets and Competition.
  Governmental Regulation.
 Regulation of oil and gas producing activities.
 
    
    Our oil and gas operations in Pennsylvania are regulated by the Department of
Environmental Resources, Division of Oil and Gas.
 
    
    Our oil and gas operations in West Virginia are regulated by the West Virginia
Division of Natural Resources.
 
    
    Our oil and gas operations in Indiana are regulated by the Indiana Department of
Natural Resources.
 
    
    Our oil and gas operations in Michigan are regulated by the Michigan Department
of Natural Resources and Environment.
 
    
    Our oil and gas operations in Ohio are regulated by the Ohio Department of
Natural Resources, Division of Oil and Gas.
 
    
    Our oil and gas operations in Tennessee are regulated by the Tennessee Department
of Environment and Conservation and the Division of Geology.
  4




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
    
    new well permit and well registration requirements, procedures and fees;
 
    
    minimum well spacing requirements;
 
    
    restriction on well locations and underground gas storage;
 
    
    certain well site restoration, groundwater protection and safety measures;
 
    
    landowner notification requirements;
 
    
    certain bonding or other security measures;
 
    
    various reporting requirements;
 
    
    well plugging standards and procedures; and
 
    
    broad enforcement powers.
 Environmental and Safety Regulation.
  Where can you find more information.
  
  
 ITEM 2.
    
    DESCRIPTION OF PROPERTIES
 Drilling Activity .
 Development WellsPeriods Ended
    
    Productive(1)
    
    
    Dry(2)December 31,
    
    Gross(3)
    
    
    Net(4)
    
    
    Gross(3)
    
    
    Net(4)2009
    
    
    94
    
    
    
    69.61
    
    
    
    
    
    
    
    2008
    
    
    129
    
    
    
    113.05
    
    
    
    
    
    
    
    223
    
    
    
    182.66
    
    
    
    
    
    
    
    
 
 (1)
    
    A productive well generally refers to a well that is not a dry hole.(2)
    
    A dry hole generally refers to a well found to be incapable of producing either
oil or gas in sufficient quantities to justify completion as an oil or gas well. The
term completion refers either to the installation of permanent equipment for the
production of oil or gas or, in the case of a dry hole, to the reporting of the
abandonment of the well to the appropriate regulatory agency.(3)
    
    A gross well is a well in which we have a working interest.(4)
    
    A net well equals the actual working interest we own in one gross well divided
by one hundred. For example, a 50% working interest in a well is one gross well, but a .50 net well.  5




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Summary of Producing Wells .
 Number of Producing WellsGross
    
    
    NetGas
    
    
    223
    
    
    
    182.66
 Production.
 AverageYear
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    Production CostEnded
    
    Production
    
    
    Average Sales Price
    
    
    (Lifting Cost)December 31,
    
    Oil (bbls)(1)
    
    
    Gas (mcf)(1)
    
    
    Liquid (Mcf)(1)
    
    
    per bbl(1)
    
    
    per mcf(1)
    
    
    Per Liquid mcf(1)
    
    
    per mcfe(1) (2)2009
    
    
    8,700
    
    
    
    4,294,800
    
    
    
    18,200
    
    
    $
    60.54
    
    
    $
    6.58
    
    
    $
    4.06
    
    
    $
    2.182008
    
    
    
    
    
    
    12,200
    
    
    
    
    
    
    $
    
    
    
    $
    7.59
    
    
    $
    
    
    
    $
    1.15
 
 (1)
    
    Mcf represents one thousand cubic feet of natural gas. Mcfe represents a thousand
cubic feet equivalent. Oil production is converted to mcfe at the rate of six mcf per
barrel (bbl).(2)
    
    Lifting costs include labor to operate the wells and related equipment, repairs
and maintenance, materials and supplies, property taxes, insurance and gathering
charges. Natural Gas and Oil Reserve Information.
 
    
    Introduce a new definition of oil and gas producing activities. This new definition
allows companies to include in their reserve base volumes from unconventional resources.
Such unconventional resources include bitumen extracted from oil sands and oil and gas
extracted from coal beds and shale formations.
 
    
    Report oil and gas reserves using an unweighted average price using the prior 12-month
period, based on the closing prices on the first day of each month, rather than year-end
pricing. This should maximize the comparability of reserve estimates among companies and
mitigate the distortion of the estimates that arises when using a single pricing date.
 
    
    Permit companies to disclose their probable and possible reserves on a voluntary basis.
Current rules limit disclosure to only proved reserves.
 
    
    Update and revise reserve definitions to reflect changes in the oil and gas industry and
new technologies. New updated definitions include by geographic area and reasonable
certainty.
 
    
    Permit the use of new technologies to determine proved reserves if those technologies
have been demonstrated empirically to lead to reliable conclusions about reserves volumes.
 
    
    Require additional disclosures regarding the qualifications of the chief technical
person who oversees the companys overall reserve estimation process. Additionally,
disclosures are required related to internal controls over reserve estimation, as well as a
report addressing the independence and qualifications of a companys reserves preparer or
auditor based on Society of Petroleum Engineers criteria.
  6




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December 31,2009
    
    
    2008Natural gas (per mcf)
    
    $
    3.87
    
    
    $
    5.71Oil (per bbl)
    
    
    61.18
    
    
    
    44.80
   7




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At December 31,2009
    
    
    2008Natural gas reserves  Proved Reserves (Mcf) (1)(4):Proved developed reserves (2)
    
    
    33,661,300
    
    
    
    15,555,900Total proved reserves of natural gas
    
    
    33,661,300
    
    
    
    15,555,900Oil reserves  Proved Reserves (Bbl) (1)(4):Proved developed reserves (2)
    
    
    63,200
    
    
    
    2,600Total proved reserves of oil
    
    
    63,200
    
    
    
    2,600Total proved reserves (Mcfe)
    
    
    34,040,500
    
    
    
    15,571,500PV-10 estimate of cash flows of proved reserves (3)(4):Proved developed reserves
    
    $
    34,913,500
    
    
    $
    14,621,900Total PV-10 estimate
    
    $
    34,913,500
    
    
    $
    14,621,900PV-10 estimate per limited partner unit (5)
    
    $
    1,221
    
    
    $
    500Undiscounted estimate per limited partner unit (5)
    
    $
    2,327
    
    
    $
    1,300
 
 (1)
    
    Proved reserves generally refers to the estimated quantities of crude oil, natural
gas, and natural gas liquids which geological and engineering data demonstrate with
reasonable certainty to be recoverable in future years from known reservoirs under
existing economic and operating conditions, i.e., prices and costs as of the date the
estimate is made. Prices include consideration of changes in existing prices provided
only by contractual arrangements, but not on escalations based upon future conditions.
Reservoirs are considered proved if economic production is supported by either actual
production or conclusive formation test. The area of a reservoir considered proved
includes: that portion delineated by drilling and defined by gas-oil and/or oil-water
contacts, if any; and the immediately adjoining portions not yet drilled, but which can
be reasonably judged as economically productive on the basis of available geological and
engineering data.(2)
    
    Proved developed reserves generally refers to reserves that can be expected to
be recovered through existing wells with existing equipment and operating methods. (Does
not include natural gas liquid reserves).(3)
    
    The present value of estimated future net cash flows is calculated by discounting
estimated future net cash flows by 10% annually.(4)
    
    Please see Regulation S-X rule 4-10 for complete definitions of each reserve
category.(5)
    
    This value per $10,000 unit is determined by following the methodology used for
determining our proved reserves using the data discussed above. However, this value does
not necessarily reflect the fair market value of a unit, and each unit is illiquid.
Also, the value of a unit for purposes of presentment of the unit to our MGP for
purchase is different, because it is calculated under a formula set forth in the
partnership agreement.  Title to Properties .
   8




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Acreage.
 Developed AcreageLocation
    
    Gross(1)
    
    
    Net(2)Indiana
    
    
    1,760.00
    
    
    
    1,462.40Michigan
    
    
    1,640.00
    
    
    
    1,495.20Ohio
    
    
    12.27
    
    
    
    1.78Pennsylvania
    
    
    4,310.94
    
    
    
    3,488.75Tennessee
    
    
    1,548.20
    
    
    
    1,325.97West Virginia
    
    
    235.07
    
    
    
    153.47Total
    
    
    9,506.48
    
    
    
    7,927.57
 
 (1)
    
    A gross acre is an acre in which we own a working interest.(2)
    
    A net acre represents the actual working interest we own in one gross acre
divided by one hundred. For example, a 50% working interest in an acre is one gross
acre, but a .50 net acre. Delivery Commitments.
      9




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ITEM 3.
    
    LEGAL PROCEEDINGS
   
 ITEM 4.
    
    (REMOVED AND RESERVED)
  
 PART II
 
 ITEM 5.
    
    MARKET FOR REGISTRANTS COMMON EQUITY AND RELATED SECURITY HOLDER MATTERS
 Market Information.
 
    
    our MGP consent;
 
    
    the transfer not result in materially adverse tax consequences to us; and
 
    
    the transfer not violate federal or state securities laws.
  
    
    the assignor gives the assignee the right;
 
    
    our MGP consents to the substitution;
 
    
    the assignee pays to us all costs and expenses incurred in connection with the
substitution; and
 
    
    the assignee executes and delivers the instruments, which our MGP requires to effect
the substitution and to confirm his or her agreement to be bound by the terms of our
partnership agreement.
  Holders.
 Distributions.
   
    
    $9,198,600 to our limited partners, and
 
    
    $3,563,300 to our managing general partner.
  10




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ITEM 7.
    
    MANAGEMENTS DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION OR PLAN OF OPERATIONS
  General .
  Results of Operations.
  Years Ended December 31,2009
    
    
    2008Production revenues (in thousands):Gas
    
    $
    28,262
    
    
    $
    93Oil
    
    
    529
    
    
    
    Liquid
    
    
    74
    
    
    
    Total
    
    $
    28,865
    
    
    $
    93Production volumes:Gas (mcf/day) (1)
    
    
    11,767
    
    
    
    719Oil (bbls/day) (1)
    
    
    24
    
    
    
    Liquid (mcf/day) (1)
    
    
    50
    
    
    
    Total (mcfe/day) (1)
    
    
    11,961
    
    
    
    719Average sales prices:Gas (per mcf) (1)
    
    $
    6.58
    
    
    $
    7.59Oil (per bbl) (1)
    
    $
    60.54
    
    
    $
    Liquid (per mcf) (1)
    
    $
    4.06
    
    
    $
    Average production costs:As a percent of revenues
    
    
    33
    %
    
    
    15
    %Per mcfe (1)
    
    $
    2.18
    
    
    $
    1.15Depletion per mcfe
    
    $
    3.86
    
    
    $
    8.70
 
 (1)
    
    Mcf represents thousand cubic feet, mcfe represents thousand cubic feet
equivalent and bbls represents barrels. Bbls are converted to mcfe using the ratio of
six mcfs to one bbl.  11




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Natural Gas Revenues
  Oil Revenues
 Natural Gas Liquids Revenue
 Expenses.
    Liquidity and Capital Resources .
    12




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




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Reserve Estimates .
 Asset Retirement Obligations
 Working Interest.
  14




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




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ATLAS RESOURCES PUBLIC 18-2008 (A) L.P.
BALANCE SHEETS
DECEMBER 31,
 2009
    
    
    2008ASSETSCurrent assets:Cash and cash equivalents
    
    $
    1,510,300
    
    
    $
    20,839,700Accounts receivable  affiliate
    
    
    5,127,800
    
    
    
    70,600Short-term hedge receivable due from affiliate
    
    
    3,846,900
    
    
    
    Total current assets
    
    
    10,485,000
    
    
    
    20,910,300Oil and gas properties, net
    
    
    130,386,300
    
    
    
    47,592,400Construction in progress
    
    
    
    
    
    
    115,371,700Long-term hedge liability due from affiliate
    
    
    3,386,700
    
    
    
    $
    144,258,000
    
    
    $
    183,874,400LIABILITIES AND PARTNERS CAPITALCurrent liabilities:Accrued liabilities
    
    $
    253,200
    
    
    $
    3,900Short-term hedge liability due to affiliate
    
    
    47,000
    
    
    
    Total current liabilities
    
    
    300,200
    
    
    
    3,900Asset retirement obligation
    
    
    1,592,900
    
    
    
    957,000Long-term hedge liability due to affiliate
    
    
    552,600
    
    
    
    Partners capital:Managing general partner
    
    
    14,734,100
    
    
    
    6,395,600Limited partners (20,152.50 units)
    
    
    122,017,900
    
    
    
    201,171,100Investor subscriptions receivable
    
    
    
    
    
    
    (24,653,200
    )Accumulated other comprehensive income
    
    
    5,060,300
    
    
    
    Total partners capital
    
    
    141,812,300
    
    
    
    182,913,500$
    144,258,000
    
    
    $
    183,874,400
   16




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ATLAS RESOURCES PUBLIC 18-2008 (A) L.P.
STATEMENTS OF OPERATIONS
FOR THE YEAR ENDED DECEMBER 31, 2009 AND PERIOD ENDED
APRIL 8, 2008 (date of formation) THROUGH
DECEMBER 31, 2008
 2009
    
    
    2008REVENUESNatural gas and oil
    
    $
    28,864,900
    
    
    $
    92,800Interest income
    
    
    3,200
    
    
    
    Total revenues
    
    
    28,868,100
    
    
    
    92,800COST AND EXPENSESProduction
    
    
    9,497,700
    
    
    
    14,100Depletion
    
    
    16,785,100
    
    
    
    106,300Impairment of oil and gas properties
    
    
    75,040,600
    
    
    
    Accretion of asset retirement obligation
    
    
    84,700
    
    
    
    39,000General and administrative
    
    
    290,300
    
    
    
    12,000Total expenses
    
    
    101,698,400
    
    
    
    171,400Net loss
    
    $
    (72,830,300
    )
    
    $
    (78,600
    )Allocation of net loss:Managing general partner
    
    $
    (2,875,700
    )
    
    $
    (6,900
    )Limited partners
    
    $
    (69,954,600
    )
    
    $
    (71,700
    )Net loss per limited partnership unit
    
    $
    (3,471
    )
    
    $
    (4
    )
   17




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ATLAS RESOURCES PUBLIC 18-2008 (A) L.P.
STATEMENTS OF COMPREHENSIVE LOSS
FOR THE YEAR ENDED DECEMBER 31, 2009 AND PERIOD ENDED
APRIL 8, 2008 (date of formation) THROUGH
DECEMBER 31, 2008
 2009
    
    
    2008Net loss
    
    $
    (72,830,300
    )
    
    $
    Other comprehensive (loss) income:Unrealized holding gain on hedging contracts
    
    
    14,867,000
    
    
    
    Less: reclassification adjustment for gain realized in net earnings
    
    
    (9,806,700
    )
    
    
    Total other comprehensive income
    
    
    5,060,300
    
    
    
    Comprehensive loss
    
    $
    (67,770,000
    )
    
    $
    
   18




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ATLAS RESOURCES PUBLIC 18-2008 (A) L.P.
STATEMENTS OF CHANGES IN PARTNERS CAPITAL
FOR THE YEAR ENDED DECEMBER 31, 2009 AND PERIOD ENDED
APRIL 8, 2008 (date of formation) THROUGH
DECEMBER 31, 2008
 AccumulatedManaging
    
    
    
    
    
    
    Other
    
    
    InvestorGeneral
    
    
    Limited
    
    
    Comprehensive
    
    
    SubscriptionPartner
    
    
    Partners
    
    
    Income
    
    
    Receivable
    
    
    TotalBalance at April 8, 2008
    
    $
    
    
    
    $
    
    
    
    $
    
    
    
    $
    
    
    
    $
    Partners capital contributions:Cash
    
    
    100
    
    
    
    201,242,800
    
    
    
    
    
    
    
    (24,653,200
    )
    
    
    176,589,700Syndication and offering costs
    
    
    10,119,500
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    10,119,500Tangible equipment/leasehold costs
    
    
    6,402,400
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    6,402,400Total contributions
    
    
    16,522,000
    
    
    
    201,242,800
    
    
    
    
    
    
    
    (24,653,200
    )
    
    
    193,111,600Syndication and offering costs, immediately
charged to capital
    
    
    (10,119,500
    )
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    (10,119,500
    )6,402,500
    
    
    
    201,242,800
    
    
    
    
    
    
    
    (24,653,200
    )
    
    
    182,992,100Participation in revenue and expenses:Net production revenues
    
    
    23,200
    
    
    
    55,500
    
    
    
    
    
    
    
    
    
    
    
    78,700Depletion
    
    
    (15,100
    )
    
    
    (91,200
    )
    
    
    
    
    
    
    
    
    
    
    (106,300
    )Accretion of asset retirement obligation
    
    
    (11,500
    )
    
    
    (27,500
    )
    
    
    
    
    
    
    
    
    
    
    (39,000
    )General and administrative
    
    
    (3,500
    )
    
    
    (8,500
    )
    
    
    
    
    
    
    
    
    
    
    (12,000
    )Net loss
    
    
    (6,900
    )
    
    
    (71,700
    )
    
    
    
    
    
    
    
    
    
    
    (78,600
    )Balance at December 31, 2008
    
    $
    6,395,600
    
    
    $
    201,171,100
    
    
    $
    
    
    
    $
    (24,653,200
    )
    
    $
    182,913,500Partners capital contributions:Syndication and offering costs
    
    
    11,136,500
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    11,136,500Total contributions
    
    
    11,136,500
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    11,136,500Syndication and offering costs, immediately
charged to capital
    
    
    (11,136,500
    )
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    (11,136,500
    )Participation in revenue and expenses:Net production revenues
    
    
    5,713,300
    
    
    
    13,653,900
    
    
    
    
    
    
    
    
    
    
    
    19,367,200Interest income
    
    
    1,000
    
    
    
    2,200
    
    
    
    
    
    
    
    
    
    
    
    3,200Depletion
    
    
    (1,550,000
    )
    
    
    (15,235,100
    )
    
    
    
    
    
    
    
    
    
    
    (16,785,100
    )Impairment of oil and gas properties
    
    
    (6,929,400
    )
    
    
    (68,111,200
    )
    
    
    
    
    
    
    
    
    
    
    (75,040,600
    )General and administrative
    
    
    (85,600
    )
    
    
    (204,700
    )
    
    
    
    
    
    
    
    
    
    
    (290,300
    )Accretion of asset retirement obligation
    
    
    (25,000
    )
    
    
    (59,700
    )
    
    
    
    
    
    
    
    
    
    
    (84,700
    )Net loss
    
    
    (2,875,700
    )
    
    
    (69,954,600
    )
    
    
    
    
    
    
    
    
    
    
    (72,830,300
    )Other comprehensive income
    
    
    
    
    
    
    
    
    
    
    5,060,300
    
    
    
    
    
    
    
    5,060,300Asset contributions
    
    
    14,777,600
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    14,777,600Return of capital
    
    
    (100
    )
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    (100
    )Distributions to partners
    
    
    (3,563,300
    )
    
    
    (9,198,600
    )
    
    
    
    
    
    
    
    
    
    
    (12,761,900
    )Subscription received
    
    
    
    
    
    
    
    
    
    
    
    
    
    
    24,653,200
    
    
    
    24,653,200Balance at December 31, 2009
    
    $
    14,734,100
    
    
    $
    122,017,900
    
    
    $
    5,060,300
    
    
    $
    
    
    
    $
    141,812,300
   19




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##### Table of Contents



ATLAS RESOURCES PUBLIC 18-2008 (A) L.P.
STATEMENTS OF CASH FLOWS
FOR THE YEAR ENDED DECEMBER 31, 2009 AND PERIOD ENDED
APRIL 8, 2008 (date of formation) THROUGH
DECEMBER 31, 2008
 2009
    
    
    2008Cash flows from operating activities:Net loss
    
    $
    (72,830,300
    )
    
    $
    (78,600
    )Adjustments to reconcile net loss to net cash used in operating activities:Depletion
    
    
    16,785,100
    
    
    
    106,300Impairment of oil and gas properties
    
    
    76,614,300
    
    
    
    Non-cash gain on derivative
    
    
    (1,573,700
    )
    
    
    Accretion of asset retirement obligation
    
    
    84,700
    
    
    
    39,000Increase in accounts receivable-affiliate
    
    
    (5,057,200
    )
    
    
    (70,600
    )Decrease in accrued liabilities
    
    
    249,300
    
    
    
    3,900Net cash provided by operating activities
    
    
    14,272,200
    
    
    
    Cash flows from investing activities:Oil and gas well drilling contracts paid to MGP
    
    
    (45,492,800
    )
    
    
    (155,750,000
    )Return of initial capital contribution by MGP
    
    
    (100
    )
    
    
    Net cash used in investing activities
    
    
    (45,492,900
    )
    
    
    (155,750,000
    )Cash flows from financing activities:Initial capital contribution by MGP
    
    
    
    
    
    
    100Distributions to partners
    
    
    (12,761,900
    )
    
    
    Partners capital contributions
    
    
    24,653,200
    
    
    
    176,589,600Net cash provided by financing activities
    
    
    11,891,300
    
    
    
    176,589,700Net (decrease) increase in cash and cash equivalents
    
    
    (19,329,400
    )
    
    
    20,839,700Cash and cash equivalents at beginning of period
    
    
    20,839,700
    
    
    
    Cash and cash equivalents at end of period
    
    $
    1,510,300
    
    
    $
    20,839,700Supplemental Schedule of non-cash investing and financing activities:Assets contributed by the managing general partner:Tangible equipment
    
    $
    13,473,800
    
    
    $
    4,920,700Lease costs
    
    
    1,303,800
    
    
    
    1,481,700Syndication and offering costs
    
    
    11,136,500
    
    
    
    10,119,500$
    25,914,100
    
    
    $
    16,521,900Asset retirement obligation
    
    $
    551,200
    
    
    $
    918,000
   20




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##### Table of Contents



ATLAS RESOURCES PUBLIC 18-2008 (A) L.P.
NOTES TO FINANCIAL STATEMENTS
DECEMBER 31, 2009 AND 2008
 NOTE 1  DESCRIPTION OF BUSINESS
   NOTE 2  SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
  Use of Estimates
  Accounts Receivable and Allowance for Possible Losses
  Revenue Recognition
   21




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ATLAS RESOURCES PUBLIC 18-2008 (A) L.P.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2009 AND 2008
 NOTE 2  SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
  Fair Value of Financial Instruments
  Supplemental Cash Flow Information
  Concentration of Credit Risk
  Comprehensive Loss
  Working Interest
   22




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ATLAS RESOURCES PUBLIC 18-2008 (A) L.P.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2009 AND 2008
 NOTE 2  SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
 Oil and Gas Properties
   December 31,2009
    
    
    2008Proved properties:Leasehold interests
    
    $
    2,785,500
    
    
    $
    1,481,700Wells and related equipment
    
    
    221,106,500
    
    
    
    46,217,000223,892,000
    
    
    
    47,698,700Accumulated depletion
    
    
    (93,505,700
    )
    
    
    (106,300
    )$
    130,386,300
    
    
    $
    47,592,400
    23




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##### Table of Contents



ATLAS RESOURCES PUBLIC 18-2008 (A) L.P.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2009 AND 2008
 NOTE 2  SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
 Asset Retirement Obligation
  Environmental Matters
   Major Customers
  Income Taxes
  Recently Issued Financial Accounting Standards
   24




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##### Table of Contents



ATLAS RESOURCES PUBLIC 18-2008 (A) L.P.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2009 AND 2008
 NOTE 2  SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
 Recently Issued Financial Accounting Standards (Continued)
  
    
    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; and
    
    Require additional disclosures regarding the qualifications of the chief technical
person who oversees the companys overall reserve estimation process. Additionally, disclosures are
required with regard to internal controls over reserve estimation, as well as a report addressing
the independence and qualifications of a companys reserves preparer or auditor based on Society of
Petroleum Engineers criteria.
    25




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##### Table of Contents



ATLAS RESOURCES PUBLIC 18-2008 (A) L.P.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2009 AND 2008
 NOTE 2  SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
 Recently Issued Financial Accounting Standards (Continued)
      26




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ATLAS RESOURCES PUBLIC 18-2008 (A) L.P.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2009 AND 2008
 NOTE 2  SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
 Recently Issued Financial Accounting Standards (Continued)
  NOTE 3  PARTICIPATION IN REVENUES AND COSTS
  ManagingGeneral
    
    
    LimitedPartner
    
    
    PartnersOrganization and offering costs
    
    
    100
    %
    
    
    0
    %Lease costs
    
    
    100
    %
    
    
    0
    %Revenues (1)
    
    
    29.50
    %
    
    
    70.50
    %Operating costs, administrative costs, direct costs and all other operating costs (2)
    
    
    29.50
    %
    
    
    70.50
    %Intangible drilling costs
    
    
    0
    %
    
    
    100
    %Tangible equipment costs
    
    
    40
    %
    
    
    60
    %
 (1)
    
    Subject to the MGPs subordination obligation, substantially all partnership
revenues will be shared in the same percentage as capital contributions are to the
total partnership capital contributions, except that the MGP will receive an additional
7% of the partnership revenues. The MGP revenue percentage may not exceed 40%.(2)
    
    These costs will be charged to the partners in the same ratio as the related
production revenues are credited. NOTE 4  CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS
  
    
    Drilling contracts to drill and complete wells for the Partnership are charged at cost
plus 18%. The cost of the wells includes reimbursement to the Partnerships MGP of its
general and administrative overhead cost. Cash and subscriptions totaling $45,492,900 were
received by the Partnerships broker/dealer and held on account at December 31, 2008. These
funds were subsequently received by the Partnership in January 2009. The Partnership paid
$176,589,600 to its MGP in 2008 under the drilling contract.
 
    
    The Partnerships MGP contributed undeveloped leases necessary to cover each of the
Partnerships prospects and as of December 31, 2009 received a credit to its capital
account in the Partnership of $2,785,500.
  27




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ATLAS RESOURCES PUBLIC 18-2008 (A) L.P.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2009 AND 2008
 NOTE 4  CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS (Continued)
 
    
    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 in 2009 and 2008 were $100,400 and $100, respectively.
 
    
    Monthly well supervision fees which are included in production expenses in the
Partnerships Statements of Operations are payable at $975 per well, per month for Marcellus
wells and $1,500, for New Albany and Indiana wells. For all other wells a fee of $392 is
charged per well per month for operating and maintaining the wells. Well supervision fees
incurred in 2009 and 2008 were $818,600 and $800, respectively.
 
    
    Transportation fees which are included in production expenses in the Partnerships
Statements of Operations are generally payable at 13% of the natural gas sales price.
Transportation fees incurred in 2009, and 2008 were $3,624,200 and $12,700, respectively.
 
    
    Direct costs which are included in production and general administrative expenses in the
Partnerships Statements of Operations are payable to the MGP and its affiliates as
reimbursement for all costs expended on the Partnerships behalf. Direct costs incurred in
2009 and 2008 were $5,244,800 and $12,500, respectively.
 
    
    Assets contributed from the MGP which are disclosed on the Partnerships Statements of
Cash Flows as non-cash investing and financing activities for the year ended December 31,
2009 and period ended December 31, 2008 were $25,914,100 and $16,521,900, respectively.
 NOTE 5  COMMITMENTS
    28




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ATLAS RESOURCES PUBLIC 18-2008 (A) L.P.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2009 AND 2008
 NOTE 6  SUBORDINATION BY MANAGING GENERAL PARTNER
  NOTE 7  DERIVATIVE INSTRUMENTS
   Asset Derivatives
    
    
    Liability DerivativesDerivatives in
    
    
    
    Fair Value
    
    
    
    
    Fair ValueCash Flow
    
    Balance Sheet
    
    December 31,
    
    
    Balance Sheet
    
    December 31,Hedging Relationships
    
    Location
    
    2009
    
    
    Location
    
    2009Commodity contracts:
    
    Current assets
    
    $
    3,846,900
    
    
    Current liabilities
    
    $
    (47,000
    )Long-term assets
    
    
    3,386,700
    
    
    Long-term liabilities
    
    
    (552,600
    )Total derivatives
    
    
    
    $
    7,233,600
    
    
    
    
    $
    (599,600
    )
  29




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ATLAS RESOURCES PUBLIC 18-2008 (A) L.P.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2009 AND 2008
 NOTE 7  DERIVATIVE INSTRUMENTS (Continued)
 Effects of Derivative Instruments on Statement of Operations:
 Gain
    
    
    
    
    GainRecognized in OCI
    
    
    
    
    Reclassified from OCI intoon Derivative
    
    
    Location of Gain/(Loss)
    
    Income(Effective Portion)
    
    
    Reclassified from
    
    (Effective Portion)Derivatives in
    
    Twelve Months Ended
    
    
    Accumulated
    
    Twelve Months EndedCash Flow
    
    December 31,
    
    
    OCI into Income
    
    December 31,Hedging Relationships
    
    2009
    
    
    (Effective Portion)
    
    2009Commodity contracts
    
    $
    14,867,000
    
    
    Natural gas and oil revenue
    
    $
    9,806,700
    Natural Gas Fixed Price Swaps
 Production
    
    
    
    
    
    AveragePeriod Ending
    
    Volumes
    
    
    Fixed Price
    
    
    Fair ValueDecember 31,
    
    (MMbtu)(1)
    
    
    (per MMbtu)(1)
    
    
    Asset(2)2010
    
    
    2,202,300
    
    
    $
    7.34
    
    
    $
    3,382,2002011
    
    
    1,130,200
    
    
    
    6.98
    
    
    
    1,046,7002012
    
    
    1,018,600
    
    
    
    7.22
    
    
    
    807,6002013
    
    
    641,400
    
    
    
    7.08
    
    
    
    244,400$
    5,480,900
  30




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ATLAS RESOURCES PUBLIC 18-2008 (A) L.P.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2009 AND 2008
 NOTE 7  DERIVATIVE INSTRUMENTS (Continued)
 Natural Gas Costless Collars
 Production
    
    
    
    
    
    
    
    AveragePeriod Ending
    
    Option
    
    Volumes
    
    
    Floor & Cap
    
    
    Fair ValueDecember 31,
    
    Type
    
    (MMbtu)(1)
    
    
    (per MMbtu)(1)
    
    
    Asset(2)2010
    
    Puts purchased
    
    
    157,900
    
    
    $
    7.84
    
    
    $
    376,6002010
    
    Calls sold
    
    
    157,900
    
    
    
    9.01
    
    
    
    2011
    
    Puts purchased
    
    
    729,900
    
    
    
    6.45
    
    
    
    444,7002011
    
    Calls sold
    
    
    729,900
    
    
    
    7.63
    
    
    
    2012
    
    Puts purchased
    
    
    347,700
    
    
    
    6.51
    
    
    
    173,3002012
    
    Calls sold
    
    
    347,700
    
    
    
    7.71
    
    
    
    2013
    
    Puts purchased
    
    
    316,300
    
    
    
    6.58
    
    
    
    108,5002013
    
    Calls sold
    
    
    316,300
    
    
    
    7.79
    
    
    
    $
    1,103,100
 Crude Oil Fixed Price Swaps
 Production
    
    
    
    
    
    AveragePeriod Ending
    
    Volumes
    
    
    Fixed Price
    
    
    Fair ValueDecember 31,
    
    (Bbl)(1)
    
    
    (per Bbl)(1)
    
    
    Asset(3)2010
    
    
    2,000
    
    
    $
    97.40
    
    
    $
    31,0002011
    
    
    1,600
    
    
    
    77.46
    
    
    
    5,5002012
    
    
    1,200
    
    
    
    76.86
    
    
    
    1,3002013
    
    
    400
    
    
    
    77.36
    
    
    
    100$
    37,900
 Crude Oil Costless Collars
 Production
    
    
    
    
    
    
    
    Average
    
    
    Fair ValuePeriod Ending
    
    Option
    
    Volumes
    
    
    Floor & Cap
    
    
    AssetDecember 31,
    
    Type
    
    (Bbl)(1)
    
    
    (per Bbl)(1)
    
    
    (Liability)(3)2010
    
    Puts purchased
    
    
    1,300
    
    
    $
    85.00
    
    
    $
    10,2002010
    
    Calls sold
    
    
    1,300
    
    
    
    112.92
    
    
    
    2011
    
    Puts purchased
    
    
    1,000
    
    
    
    67.22
    
    
    
    1,8002011
    
    Calls sold
    
    
    1,000
    
    
    
    89.44
    
    
    
    2012
    
    Puts purchased
    
    
    800
    
    
    
    65.51
    
    
    
    2002012
    
    Calls sold
    
    
    800
    
    
    
    91.45
    
    
    
    2013
    
    Puts purchased
    
    
    200
    
    
    
    65.36
    
    
    
    2013
    
    Calls sold
    
    
    200
    
    
    
    93.44
    
    
    
    (100
    )$
    12,100Total Net Asset
    
    $
    6,634,000
 
 (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.  31




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ATLAS RESOURCES PUBLIC 18-2008 (A) L.P.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2009 AND 2008
 NOTE 8  FAIR VALUE OF FINANCIAL INSTRUMENTS
  Level 1
    
    Unadjusted quoted prices in active markets for identical assets and
liabilities that the reporting entity has the ability to access at the measurement date.
 Level 2
    
    Inputs other than quoted prices included within Level 1 that are observable
for the asset and liability or can be corroborated with observable market data for
substantially the entire contractual term of the asset or liability.
 Level 3
    
    Unobservable inputs that reflect the 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
  December 31, 2009
    
    
    December 31, 2008Level 2
    
    
    Total
    
    
    Level 2
    
    
    TotalCommodity-based derivatives
    
    $
    6,634,000
    
    
    $
    6,634,000
    
    
    $
    
    
    
    $
    Total
    
    $
    6,634,000
    
    
    $
    6,634,000
    
    
    $
    
    
    
    $
    
  32




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##### Table of Contents



ATLAS RESOURCES PUBLIC 18-2008 (A) L.P.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2009 AND 2008
 NOTE 8  FAIR VALUE OF FINANCIAL INSTRUMENTS (Continued)
 Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
   NOTE 9  ASSET RETIREMENT OBLIGATION
    December 31,2009
    
    
    2008Asset retirement obligation at beginning of period
    
    $
    957,000
    
    
    $
    Liabilities incurred from drilling wells
    
    
    512,500
    
    
    
    918,000Revision in estimate
    
    
    38,700
    
    
    
    Accretion expense
    
    
    84,700
    
    
    
    39,000Asset retirement obligation at end of period
    
    $
    1,592,900
    
    
    $
    957,000
  33




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ATLAS RESOURCES PUBLIC 18-2008 (A) L.P.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2009 AND 2008
 NOTE 10  NATURAL GAS AND OIL PRODUCING ACTIVITIES (UNAUDITED)
 (1) Capitalized Costs Related to Oil and Gas Producing Activities
  At December 31,2009
    
    
    2008Mineral interest in proved properties:
    
    $
    2,785,500
    
    
    $
    1,481,700Wells and related equipment
    
    
    221,106,500
    
    
    
    46,217,000Accumulated depletion
    
    
    (93,505,700
    )
    
    
    (106,300
    )Net capitalized cost
    
    $
    130,386,300
    
    
    $
    47,592,400
 (2) Oil and Gas Reserve Information
      34




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##### Table of Contents



ATLAS RESOURCES PUBLIC 18-2008 (A) L.P.
NOTES TO FINANCIAL STATEMENTS  (Continued)
DECEMBER 31, 2009 AND 2008
 NOTE 10  NATURAL GAS AND OIL PRODUCING ACTIVITIES (UNAUDITED) (Continued)
 Natural Gas
    
    
    Oil(Mcf)
    
    
    (Bbls)Proved developed reserves:Beginning of period
    
    
    
    
    
    
    Extensions, discoveries and other additions
    
    
    15,568,100
    
    
    
    2,600Production
    
    
    (12,200
    )
    
    
    Balance December 31, 2008
    
    
    15,555,900
    
    
    
    2,600Production
    
    
    (4,294,800
    )
    
    
    (8,700
    )Revision to previous estimates
    
    
    (2,508,500
    )
    
    
    23,200Extensions, discoveries and other additions
    
    
    24,908,700
    
    
    
    46,100Balance December 31, 2009
    
    
    33,661,300
    
    
    
    63,200
 
 ITEM 9.
    
    CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE:
  
 ITEM 9A.
    
    CONTROLS AND PROCEDURES
 Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures
    35




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Managements Report on Internal Control over Financial Reporting
 Internal Control  Integrated
Framework
    
 ITEM 9B.
    
    OTHER INFORMATION
  
 PART III
 
 ITEM 10.
    
    DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
 nd
 Executive Officers and Directors.
 NAME
    
    AGE
    
    POSITION OR OFFICEFreddie M. Kotek
    
    
    54
    
    
    Chairman of the Board of Directors, Chief Executive
Officer and PresidentFrank P. Carolas
    
    
    50
    
    
    Executive Vice President  Land and Geology and a DirectorJeffrey C. Simmons
    
    
    51
    
    
    Executive Vice President  Operations and a DirectorJack L. Hollander
    
    
    53
    
    
    Senior Vice President  Direct Participation ProgramsSean P. McGrath
    
    
    38
    
    
    Chief Accounting OfficerMatthew A. Jones
    
    
    48
    
    
    Chief Financial Officer
  36




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##### Table of Contents




    
    the approximate amount of an individuals professional time devoted to the business and
affairs of our MGP and Atlas America have been aggregated because there is no reasonable
method for them to distinguish their activities between the two companies; and
 
    
    for those individuals who also hold senior positions with other affiliates of our MGP,
if it is stated that they devote approximately 100% of their professional time to our MGP
and Atlas America, it is because either the other affiliates are not currently active in
drilling new wells, such as Viking Resources or Resource Energy, and the individuals are
not required to devote a material amount of their professional time to the affiliates, or
there is no reasonable method to distinguish their activities between our MGP and Atlas
America as compared with the other affiliates of our MGP, such as Viking Resources or
Resource Energy.
 Freddie M. Kotek
 Frank P. Carolas.
 Jeffrey C. Simmons.
  37




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##### Table of Contents



Jack L. Hollander.
 Sean P. McGrath
 Matthew A. Jones
 Audit Committee Financial Expert.
 Remuneration of Officers and Directors.
 Code of Business Conduct and Ethics. nd
  38




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##### Table of Contents



ITEM 11.
    
    EXECUTIVE COMPENSATION
 Certain Relationships and Related Party Transactions
 
 ITEM 12.
    
    SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
  Organizational and Security Ownership of Beneficial Owners.
 
 ITEM 13.
    
    CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS
 Oil and Gas Revenues.
 Leases.
 Administrative Costs.
 Drilling Contracts.
  39




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##### Table of Contents



Well Charges.
 Dealer-Manager Fees.
 Direct Costs.
 Transportation Fees.
 Other Compensation.
 
 ITEM 14.
    
    PRINCIPAL ACCOUNTANT FEES AND SERVICES
 Audit Fees.
 Procedures for Audit Committee Pre-Approval of Audit and Permissible Non-Audit Services of
Independent Auditor.
  40




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##### Table of Contents



PART IV
 
 ITEM 15.
    
    EXHIBITS
 
 EXHIBIT INDEX
 Description
    
    Location4(a)
    
    
    Certificate of Limited Partnership for Atlas Resources Public 18-2008 (A) L.P.
    
    Previously filed in our Form S-1/A on October 10, 20074(b)
    
    
    Amended and Restated Certificate and Agreement of Limited Partnership for Atlas
Resources Public 18-2008 (A) L.P.(1)
    
    Previously filed in our Form S-1/A on October 10, 20074(c)
    
    
    Drilling and Operating Agreement for Atlas Resources Public 18-2008 (A) L.P.
(1)
    
    Previously filed in our Form S-1/A on October 10, 200723.1
    
    
    Consent of Wright and Company, Inc.31.1
    
    
    Rule 13a-14(a)/15(d) - 14 (a) Certification31.2
    
    
    Rule 13a-14(a)/15(d) - 14 (a) Certification.32.1
    
    
    Section 1350 Certification.32.2
    
    
    Section 1350 Certification.99.1
    
    
    Summary Reserve Report
 
 (1)
    
    Filed on October 15, 2008 in the Form S-1A Registration Statement dated October 15,
2008, File No. 333-150925-03  41




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##### Table of Contents



SIGNATURES
   Date:  March 30, 2010
    Atlas Resources, LLC, Managing General PartnerBy:
    /s/ Freddie M. KotekFreddie M. Kotek, Chairman of the Board of Directors,Chief Executive Officer and President  Date:  March 30, 2010
    By:
    /s/ Freddie M. KotekFreddie M. Kotek, Chairman of the Board of Directors,Chief Executive Officer and PresidentDate:  March 30, 2010
    By:
    /s/ Frank P. CarolasFrank P. Carolas, Executive Vice President  Land and GeologyDate:  March 30, 2010
    By:
    /s/ Jeffrey C. SimmonsJeffrey C. Simmons, Executive Vice President  OperationsDate:  March 30, 2010
    By:
    /s/ Sean P. McGrathSean P. McGrath, Chief Accounting OfficerDate:  March 30, 2010
    By:
    /s/ Matthew A. JonesMatthew A. Jones, Chief Financial Officer Supplemental information to be furnished with reports filed pursuant to Section 15(d) of the
Exchange Act by Non-reporting Issuers
   42