CONFORMED COPY

QUARTERLY REPORTUNDER SECTION 13 OR 15(d)

OF THE SECURITIESEXCHANGE ACT OF 1934

UNITED STATES

SECURITIES ANDEXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

[X] Quarterly ReportPursuant to Section 13 or 15(d) of

the SecuritiesExchange Act of 1934

For the period ended March 31, 2005

or

[ ] TransitionReport Pursuant to Section 13 of 15(d) of

the SecuritiesExchange Act of  1934

For the transitionperiod from         to

Commission filenumber 000-50615

I.R.S. EmployerIdentification Number 30-0059674

PDC 2003-A LIMITEDPARTNERSHIP

(A West VirginiaLimited Partnership)

103 East Main  Street

Bridgeport, WV 26330

Telephone: (304)842-6256

Indicate by check mark whether the registrant (1) hasfiled 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 periodthat the registrant was required to file such reports), and (2) has beensubject to such filing requirements for the past 90 days.  Yes     XX       No        

Indicate by check mark whether the registrant is anaccelerated filer (as definition in Rule 12b-2 of the Exchange Act.) Yes            No    XX    

PDC 2003-A LIMITEDPARTNERSHIP

(A West VirginiaLimited Partnership)

INDEX

| PART I - FINANCIAL INFORMATION | Page No. |  
 
Item 1.

Item   Financial Statements

Balance Sheets - March 31, 2005 (unaudited) and December 31, 2004

1

 
 
Statements of Operations -  Three Months Ended March 31, 2005 and 2004 

(unaudited)

2

 
 
Statement of Partners' Equity - Three Months Ended March 31, 2005 (unaudited)

3

 
 
Statements of Cash Flows - Three Months Ended March 31, 2005 and 2004 (unaudited)

4

 
 
Notes to Financial Statements

5 

 
 
Item 2.

Management's Discussion and Analysis of Financial 

Condition and Results of Operations

  6

 
 
Item 3.

Quantitative and Qualitative Disclosure About Market  Rate Risk

9

 
 
Item 4.

Controls and Procedures

10

 
 
PART II  OTHER INFORMATION

 
 
Item 1.

Legal Proceedings

11

 
 
Item 6.

Exhibits 

11

 
 
 
PDC 2003-A LIMITEDPARTNERSHIP

(A West VirginiaLimited Partnership)

Balance Sheets

March 31, 2005 and December 31, 2004

      Assets

2005

2004

(Unaudited)

Current assets:

 Cash 

$         4,711

4,535

 Accounts receivable - oil and gas revenues

   374,445

   506,920

 Due from managing general partner

        314

                            -

          Total  current assets

379,470

511,455

Oil and gas properties, successful efforts method

9,231,819

9,231,819

     Less accumulated  depreciation, depletion 

        and amortization

 1,876,562

 1,710,621

 7,355,257

 7,521,198

$7,734,727

 8,032,653

     Liabilities and  Partners' Equity

Current liabilities:

 Accrued expenses

$     55,907

   113,182

          Total  current liabilities

55,907

113,182

Asset retirement obligations

7,286

7,178

Partners' Equity

7,671,534

7,912,293

$7,734,727

 8,032,653

See accompanying notes to financial statements.

-1-

PDC 2003-A LIMITEDPARTNERSHIP

(A West VirginiaLimited Partnership)

Statements ofOperations

Three Months ended March 31, 2005 and 2004

(Unaudited)

                                                                                                                                                           

2005

     2004

Revenues:

Sales of oil and gas

$476,510

689,391

Interest income

        490

            205

477,000

689,596

Expenses:

Lifting cost

80,020

                             99,640

Direct administrative

108

                                -

Depreciation, depletion,  and amortization

165,941

246,069

270,501

370,141

Net income

$230,931

319,455

Net income per limited partner unit

$436

        603

                See accompanying notes to financialstatements.

-2-

PDC 2003-A LIMITEDPARTNERSHIP

(A West VirginiaLimited Partnership)

Statement ofPartners' Equity and Comprehensive Income (Loss)

Three months ended March 31, 2005

(Unaudited)

Limited and

Additional

General  Partners

   Managing

General Partner

Accumulated

Other

Comprehensive

Income (loss)

                                        Total

Balance December 31, 2004

$6,377,933  

1,594,486 

(60,126)

7,912,293 

Distributions to partners

(391,293)

(97,823)

-    

(489,116)

Comprehensive income:

Net income

 184,745 

46,186 

-    

230,931 

Change in fair value of 

  outstanding hedging positions

 

 

   14,482

 

Less reclassification adjustments   for  settled contracts included in 

  net income

 

 

 

          2,944 

 

Other comprehensive income

              17,426

               17,426

Comprehensive income

                   

                   

                 

    248,357 

Balance March 31, 2005

$ 6,171,385 

 1,542,849 

    (42,700)

 7,671,534 

    See accompanying notes to financial statements.

-3-

PDC 2003-A LIMITEDPARTNERSHIP

(A West VirginiaLimited Partnership)

Statements of CashFlows

Three Months ended March 31, 2005 and 2004

(Unaudited)

        2005

        2004

Cash flows from operating activities:

Net income 

          $230,931 

319,455 

Adjustments to reconcile net income to net cash

  provided from operating activities:

  Depreciation, depletion and amortization

            165,941 

270,501 

   Accretion of asset retirement obligation

                  108

                    -

  Changes in operating assets and  liabilities:

 Decrease in accounts receivable - oil and gas  revenues

             95,027

199,197 

 Increase in due from managing general partner

                 (  314) 

                    -

  Decrease in accounts payable 

               (2,401)

    (3,134)

         Net  cash provided from operating activities

              489,292    

 786,019   

Cash flows from financing activities:

  Distributions to partners

            (489,116)

 (788,947)

          Net  cash used by financing activities 

             (489,116)

(788,947)

Net increase (decrease) in cash

                      176 

(2,928) 

Cash at beginning of period

          4,535  

      7,660  

Cash at end of period

$      4,711  

      4,732  

Seeaccompanying notes to financial statements.

-4-

PDC 2003-A LIMITED PARTNERSHIP

(A West VirginiaLimited Partnership)

Notes to FinancialStatements

(Unaudited)

1.     AccountingPolicies

        Referenceis hereby made to PDC 2003-A Limited Partnership's (the Partnership's) AnnualReport on Form 10-K for 2004, which contains a summary of significantaccounting policies followed by the Partnership in the preparation of itsfinancial statements.  These policies were also followed in preparing thequarterly report included herein. 

2.     Basisof Presentation

        TheManagement of the Partnership believes that all adjustments (consisting of onlynormal recurring accruals) necessary to a fair statement of the results of suchperiods have been made.  The results of operations for the three months ended March 31, 2005 are not necessarily indicative of the results to be expected for the fullyear. 

3.     Oiland Gas Properties

The Partnershipfollows the successful efforts method of accounting for the cost of exploringfor and developing oil and gas reserves.  Under this method, costs ofdevelopment wells, including equipment and intangible drilling costs related toboth producing wells and developmental dry holes, and successful exploratorywells are capitalized and amortized on an annual basis to operations by theunits-of-production method using estimated proved developed reserves determinedat year end by Petroleum Development Corporation's (the Managing GeneralPartner's) petroleum engineers.  If a determination is made that an exploratorywell has not discovered economically producible reserves, then its costs areexpensed as dry hole cost. 

The Partnershipassesses impairment of capitalized costs of proved oil and gas properties bycomparing net capitalized costs to undiscounted future net cash flows on afield-by-field basis using expected prices.  Prices utilized in each year'scalculation for measurement purposes and expected costs are held constantthroughout the estimated life of the properties.  If net capitalized costexceeds undiscounted future net cash flow, the measurement of impairment isbased on estimated fair value which would consider future discounted cashflows.

        

4.     RevenueRecognition

Sales of natural gas are recognized whennatural gas has been delivered to a custody transfer point, persuasive evidenceof a sales arrangement exists, the rights and responsibility of ownership passto the purchaser upon delivery, collection of revenue from the sale isreasonably assured and the sales price is fixed or determinable.  Natural gasis sold by the Managing General Partner under contracts with terms ranging fromone month to three years.  Virtually all of the Managing General Partner'scontracts pricing provisions are tied to a market index, with certain adjustmentsbased on, among other factors, whether a well delivers to a gathering ortransmission line, quality of natural gas and prevailing supply and demandconditions, so that the price of the natural gas fluctuates to remaincompetitive with other available natural gas supplies. As a result, thePartnership's revenues from the sale of natural gas will suffer if marketprices decline and benefit if they increase. The Partnership believes that thepricing provisions of its natural gas contracts are customary in the industry.

The Managing General Partner currentlyuses the "Net-Back" method of accounting for transportation arrangements ofnatural gas sales.  The Managing General Partner sells gas at the wellhead andcollects a price and recognizes revenues based on the wellhead sales pricesince transportation costs downstream of the wellhead are incurred by theManaging General Partner's customers and reflected in the wellhead price.

Salesof oil are recognized when persuasive evidence of a sales arrangement exists,the oil is verified as produced and is delivered in a stock tank, collection ofrevenue from the sale is reasonably assured and the sales price isdeterminable.  The Partnership is currently able to sell all the oil that itcan produce under existing sales contracts with petroleum refiners andmarketers.  The Partnership does not refine any of its oil production.  ThePartnership's crude oil production is sold to purchasers at or near thePartnership's wells under short-term purchase contracts at prices and inaccordance with arrangements that are customary in the oil industry.

-5-

PDC 2003-A LIMITEDPARTNERSHIP

(A West VirginiaLimited Partnership)

Notes to FinancialStatements

(Unaudited)

5.     Derivative Instruments and Hedging Activities

The Managing GeneralPartner utilizes commodity based derivative instruments as hedges to manage aportion of     the Partnership's exposure to price volatility stemming from oiland natural gas production. These instruments consist of CIG (Colorado InterstateGas index) based contracts for oil and natural gas futures and option contractsfor gas production and NYMEX traded oil futures and option contracts for oilproduction.  The costless collars and option contracts hedge committed andanticipated oil and natural gas sales generally forecasted to occur within a 24month period. The Partnership does not hold or issue derivatives for trading orspeculative purposes. 

   All derivativesare recognized on the Partnership balance sheet at their fair value. On thedate the derivative contract    is entered into, the Managing General Partnerdesignates the derivative as either a hedge of a forecasted transaction     orthe variability of cash flows to be received or paid related to a recognizedasset or liability ("cash flow" hedge),      or a non-hedging derivative. TheManaging General Partner formally documents all relationships betweenhedging      instruments and hedged items, as well as its risk-managementobjective and strategy for undertaking various hedge      transactions. Thisprocess includes linking all derivatives that are designated as cash-flowhedges to specific firm       commitments. The Managing General Partner alsoformally assesses, both at the hedge's inception and on an               ongoingbasis, whether the derivatives that are used in hedging transactions are highlyeffective in offsetting changes    in cash flows of hedged items.  When it isdetermined that a derivative is not highly effective as a hedge or thatit         has ceased to be a highly effective hedge, the Partnershipdiscontinues hedge accounting prospectively. No hedging    activities werediscontinued during 2005 or 2004.

   Changes in fairvalue of a derivative that is highly effective and that is designated andqualifies as a cash-flow hedge    are recorded in accumulated othercomprehensive income, until earnings are affected by the variability in cashflows    of the designated hedged item. Changes in the fair value ofnon-hedging derivatives are reported in current-period       earnings. ThePartnership discontinues hedge accounting prospectively when it is determinedthat the derivative is       no longer effective in offsetting changes in thecash flows of the hedged item, the derivative expires or is sold,             terminated,or exercised.  Additionally, if the derivative is designated as a hedginginstrument, because it is probable    that a forecasted transaction will notoccur, or the Partnership determines that designation of the derivative asa            hedging instrument is no longer appropriate, hedge accounting willbe discontinued.

   By using derivative financialinstruments to hedge exposures to changes in commodity prices, theManaging          General Partner exposes the Partnership to credit risk. Creditrisk is the failure of the counterparty to perform        under the terms ofthe derivative contract. When the fair value of a derivative contract ispositive, the                     counterparty owes the Partnership, whichcreates credit risk. The Managing General Partner minimizes the            credit risk in derivative instruments by entering into transactions withhigh-quality counterparties.

Item 2.          Management's Discussion and Analysis of FinancialCondition and Results of Operations

Liquidityand Capital Resources

The Partnership was funded on April 30, 2003 with initial Limited and Additional General Partner contributions of $8,483,045 (424.15units) and the Managing General Partner's cash contribution of $1,845,062 inaccordance with the Limited Partnership Agreement.  After payment ofsyndication costs of $890,720 and a one-time management fee to the ManagingGeneral Partner of $212,076 the Partnership had available cash of $9,225,311for Partnership activities.

The Partnershipbegan exploration and development activities subsequent to the funding of thePartnership and completed well drilling activities by December 31, 2003.  Twenty-five wells have been drilled, all of which have been completed as producingwells.   No additional wells will be drilled.

ThePartnership had working capital at March 31, 2005 of $323,563.

-6-

PDC 2003-A LIMITEDPARTNERSHIP

(A West VirginiaLimited Partnership)

Notes to FinancialStatements

(Unaudited)

Operations areexpected to be conducted with available funds and revenues generated from oiland gas activities.  No bank borrowings are anticipated.  

 

Resultsof Operations
Three months ended March 31, 2005 compared with March 31,2004
Oiland gas sales for the three months ended March 31, 2005 were $476,510 compared to $689,391 for the three months ended March 31, 2004.  For the three months ended March 31, 2005, the Partnership sold 56,725 Mcf of gas and 3,550barrels of oil sold at average sales prices of $5.56 and $45.39 respectively. This compared with 95,429 Mcf of gas and 8,288 barrels of oil at average pricesof $4.33 and $33.27, respectively, for the three months ended March 31, 2004.  Lifting cost per Mcfe for the three months ended March 31, 2005 amounted to $1.03 as compared to $0.69 per Mcfe for the three months ended March 31, 2004.  The fixed costs of operations and well maintenance were allocated tolower production volumes, therefore increasing the lifting cost per Mcfe. Depreciation, depletion, and amortization was $165,941 for the three monthsended March 31, 2005 and $270,501 for the three months ended March 31, 2004.  Cash distributions to the partners amounted to $489,116 for the three months ended March 31, 2005 and $788,947 for the three months ended March 31, 2004. 

The Partnership's revenue from oil and gas will beaffected by changes in prices.  As a result of changes in federal regulations,gas prices are highly dependent on the balance between supply and demand.  ThePartnership's gas sales prices are subject to increase and decrease based onvarious market sensitive indices.

 

CriticalAccounting Policies

 Certain accounting policies are very importantto the portrayal of the Partnership's financial condition and results ofoperations and require management's most subjective or complex judgments.  Inapplying those policies, our management uses its judgment to determine theappropriate assumptions to be used in the determination of certain estimates.Those estimates are based on our historical experience, our observance of trendsin the industry, and information available from other outside sources, asappropriate. The Partnership's critical accounting policies and estimates areas follows:

 

Revenue Recognition.  Salesof natural gas are recognized when natural gas has been delivered to a custodytransfer point, persuasive evidence of a sales arrangement exists, the rightsand responsibility of ownership pass to the purchaser upon delivery, collectionof revenue from the sale is reasonably assured and the sales price is fixed ordeterminable.  Natural gas is sold by the Managing General Partner undercontracts with terms ranging from one month to three years.  Virtually all ofthe Managing General Partner's contracts pricing provisions are tied to amarket index, with certain adjustments based on, among other factors, whether awell delivers to a gathering or transmission line, quality of natural gas andprevailing supply and demand conditions, so that the price of the natural gasfluctuates to remain competitive with other available natural gas supplies.  Asa result, the Partnership's revenues from the sale of natural gas will sufferif market prices decline and benefit if they increase. The Partnership believesthat the pricing provisions of its natural gas contracts are customary in theindustry.

TheManaging General Partner currently uses the "Net-Back" method of accounting fortransportation arrangements of natural gas sales.  The Managing General Partnersells gas at the wellhead and collects a price and recognizes revenues based onthe wellhead sales price since transportation costs downstream of the wellheadare incurred by the Managing General Partner's customers and reflected in thewellhead price.

Salesof oil are recognized when persuasive evidence of a sales arrangement exists,the oil is verified as produced and is delivered in a stock tank, collection ofrevenue from the sale is reasonably assured and the sales price isdeterminable.  The Partnership is currently able to sell all the oil that itcan produce under existing sales contracts 

-7-

PDC 2003-A LIMITEDPARTNERSHIP

(A West VirginiaLimited Partnership)

Notes to FinancialStatements

(Unaudited)

withpetroleum refiners and marketers.  The Partnership does not refine any of itsoil production.  The Partnership's crude oil production is sold to purchasersat or near the Partnership's wells under short-term purchase contracts atprices and in accordance with arrangements that are customary in the oilindustry.

Impairment of Long-Lived Assets. The Partnershipassesses impairment of capitalized costs of proved oil and gas properties bycomparing net capitalized costs to undiscounted future cash flows on afield-by-field basis using expected prices. Prices utilized in each year'scalculation for measurement purposes and expected costs are held constantthroughout the life of the properties. If net capitalized costs exceedundiscounted future net cash flow, the measurement of impairment is based onestimated fair value which would consider future discounted cash flows.

Oil and Gas Properties 

Exploration anddevelopment costs are accounted for by the successful efforts method.

The Partnership assesses impairment of capitalized costsof proved oil and gas properties by comparing net capitalized costs to estimatedundiscounted future cash flows on a field-by-field basis using expected prices.Prices utilized in each year's calculation for measurement purposes andexpected costs are held constant throughout the estimated life of theproperties. If net capitalized costs exceed undiscounted future net cash flow,the measurement of impairment is based on estimated fair value which wouldconsider future discounted cash flows.

Property acquisition costs are capitalized whenincurred.  Geological and geophysical costs and delay rentals are expensed asincurred.  The costs of drilling exploratory wells are capitalized pendingdetermination of whether the wells have discovered economically produciblereserves.  If reserves are not discovered, such costs are expensed as dry holes. Development costs, including equipment and intangible drilling costs related toboth producing wells and developmental dry holes are capitalized.

Unproved properties and leases are written-off to expensewhen it is determined that they will expire to be abandoned.

Costs of proved properties, including leaseholdacquisitions, exploration and development costs and equipment, are depreciatedand depleted by the unit-of-production method based on estimated proveddeveloped oil and gas reserves.

Upon sale or retirement of complete fields of depreciableor depletable property, the book value thereof, less proceeds or salvage value,is credited or charged to income.  Upon sale of a partial unit of property, theproceeds are credited to accumulated depreciation and depletion.

 

Recently Issued Accounting Pronouncements

 

AssetRetirement Obligations

On March 30, 2005, the FASB issued FASB Interpretation No. 47, "Accounting forConditional Asset Retirement Obligations" (FIN No. 47).  This interpretationclarifies that the term "conditional asset retirement obligation" as used inStatement No. 143 refers to a legal obligation to perform an asset retirementactivity in which the timing and/or method of settlement are conditional on afuture event that may or may not be within the control of the entity incurringthe obligation.  The obligation to perform the asset retirement activity isunconditional even though uncertainty exists about the timing and/or method ofsettlement.  Thus, the timing and/or method of settlement may be conditional ona future event.  Accordingly, an entity is required to recognize a liabilityfor the fair value of a conditional asset retirement obligation if the fairvalue of the liability can be reasonably estimated.  Uncertainty about the timingand/or method of settlement of a conditional asset retirement obligation shouldbe factored into the measurement of the liability, rather than the timing ofrecognition of the liability, when sufficient information exists. FIN No. 47will be effective for the Partnership at the end of the fiscal year ended December 31, 2005. The Partnership has not determined the impact on the Partnership'sfinancial position or results of operations of the application of FIN No. 47.

-8-

PDC 2003-A LIMITEDPARTNERSHIP

(A West VirginiaLimited Partnership)

Notes to FinancialStatements

(Unaudited)

 

DisclosureRegarding Forward Looking Statements

This Form 10-Q contains "forward-lookingstatements" within the meaning of Section 27A of the Securities Act of 1933, asamended (the "Securities Act"), and Section 21E of the Securities Exchange Actof 1934, as amended (the "Exchange Act"). All statements other than statementsof historical facts included in and incorporated by reference into this Form10-Q are forward-looking statements. These forward-looking statements aresubject to certain risks, trends and uncertainties that could cause actualresults to differ materially from those projected. Among those risks, trendsand uncertainties are the Managing General Partner's estimate of thesufficiency of its existing capital sources, its ability to raise additionalcapital to fund cash requirements for future operations, the uncertaintiesinvolved in estimating quantities of proved oil and natural gas reserves, inprospect development and property acquisitions and in projecting future ratesof production, the timing of development expenditures and drilling of wells,and the operating hazards attendant to the oil and gas business. In particular,careful consideration should be given to cautionary statements made in thevarious reports the Partnership has filed with the Securities and ExchangeCommission. The Partnership undertakes no duty to update or revise theseforward-looking statements. 

When used in the Form 10-Q, the words,"expect," "anticipate," "intend," "plan," "believe," "seek," "estimate" andsimilar expressions are intended to identify forward-looking statements,although not all forward-looking statements contain these identifying words.Because these forward-looking statements involve risks and uncertainties,actual results could differ materially from those expressed or implied by theseforward-looking statements for a number of important reasons, including thosediscussed under "Management's Discussions and Analysis of Financial Conditionand Results of Operations" and elsewhere in this Form 10-Q. 

Item 3.          Quantitativeand Qualitative Disclosure About Market Rate Risk

Market-SensitiveInstruments and Risk Management

The Partnership's primary market risk exposure is commodityprice risk.  This exposure is discussed in detail below:

Commodity Price Risk

The Managing GeneralPartner utilizes commodity-based derivative instruments as hedges to manage aportion of its exposure to price risk from its oil and natural gas sales. These instruments consist of CIG (Colorado Interstate Gas Index)- basedcontracts for natural gas futures and option contracts for gas production andNYMEX traded oil futures and option contracts for oil production. These hedgingarrangements have the effect of locking in for specified periods (atpredetermined prices or ranges of prices) the prices the Managing GeneralPartner will receive for the volume to which the hedge relates.  As a result,while these hedging arrangements are structured to reduce the Partnership'sexposure to changes in price associated with the hedged commodity, they alsolimit the benefit the Partnership might otherwise have received from pricechanges associated with the hedged commodity. The Partnership's policy prohibitsthe use of natural gas and oil future and option contracts for speculativepurposes.

The following tablessummarize the open futures and options contracts for the Partnership as of March 31, 2005 and 2004.

Commodity

Type

Quantity

Gas-Mmbtu

Oil-Barrels

Weighted

Average   Price

Total

Contract

Amount

Fair

Market

Value

Total Contracts as of March 31, 2005

Natural Gas

Floors

53,205

4.19

-

1,420  

Natural Gas

Ceilings

26,652

6.69

-

(29,289)

Oil

        Floors

1,784

32.30

57,958

58  

Oil

      Ceilings

897

40.00

35,887

(14,889)

-9-

PDC 2003-A LIMITEDPARTNERSHIP

(A West VirginiaLimited Partnership)

Notes to FinancialStatements

(Unaudited)

Contracts maturing in 12 months following March 31, 2005

Natural Gas

Floors

39,117

4.07

-    

                 576

Natural Gas

Ceilings

19,559

6.48

-    

(26,421)

Oil

Floors

1,794

32.30

57,958

58 

Oil

Ceilings

897

40.00

25,887

(14,889)

Prior Year Total Contracts as of March 31, 2004

Natural Gas

Floors

67,305

3.45

-    

- 

Natural Gas

Ceilings

33,652

4.59

                  -

(10,786)

Oil

Sales

12,215

31.63

386,352

(16,056)

The maximum term over which the Partnership is hedgingexposure to the variability of cash flows for commodity price risk is 19months.                               

Disclosure of Limitations

As the information above incorporates only thoseexposures that exist at March 31, 2005, it does not consider those exposures orpositions which could arise after that date. As a result, the Partnership'sultimate realized gain or loss with respect to commodity price fluctuationswill depend on the exposures that arise during the period, the Partnership'shedging strategies at the time and commodity prices at the time.

Item 4.          Controls and Procedures

Under the supervision and with the participation of theManaging General Partner's management, including the Managing General Partner'sChief Executive Officer and Chief Financial Officer, the Managing GeneralPartner has evaluated the effectiveness of the design and operation of itsdisclosure controls and procedures (as defined in Exchange Act Rule 13a-15(e))as of the end of this fiscal quarter, and, based on their evaluation, the ChiefExecutive Officer and Chief Financial Officer have concluded that thesedisclosure controls and procedures are effective in all material respects,including those to ensure that information required to be disclosed in reportsfiled or submitted under the Securities Exchange Act is recorded, processed,summarized, and reported, within the time periods specified in the Commission'srules and forms, and is accumulated and communicated to management, includingthe Managing General Partner's Chief Executive Officer and Chief FinancialOfficer, as appropriate to allow for timely disclosure. There have been nosignificant changes in our internal control over financial reporting or inother factors that have materially affected or are reasonably likely tomaterially affect these controls that occurred during the Partnership's lastfiscal quarter and subsequent to the date of their evaluation.

-10-

CONFORMED COPY

PART II - OTHERINFORMATION

Item1.     Legal Proceedings

            None.

Item 6.    Exhibits

           

Exhibit Name

Exhibit 

Number

Rule  13a-14(a)/15d-14(a) Certifications by

 Chief Executive  Officer

31

Rule  13a-14(a)/15d-14(a)Certification by

 Chief  Financial Officer

31

Title 18 U.S.C.  Section 1350 (Section 906 of Sarbanes-Oxley Act of 2002) Certifications by  Chief Executive Officer and Chief Financial Officer of Petroleum Development  Corporation, the managing general partner of the Limited Partnership

32

                                                                                         SIGNATURES

     Pursuant to the requirements of the SecuritiesExchange Act of 1934 the registrant has duly caused this report to be signed onits behalf by the undersigned thereunto duly authorized.

PDC 2003-A Limited Partnership

       (Registrant)

  By its Managing General Partner

Petroleum Development Corporation

 

 

  Date:  May 13, 2005

  /s/ Steven R. Williams        

      Steven R. Williams

        Chairman

  Date: May 13, 2005

  /s/ Darwin L. Stump    

      Darwin L. Stump

      Chief Financial Officer

-11- |
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