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 033-63635-04

I.R.S. EmployerIdentification Number 55-0751154

PDC 1996-D 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 1996-D 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 and Comprehensive Income (Loss) - 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 1996-D LIMITEDPARTNERSHIP

(A West VirginiaLimited Partnership)

Balance Sheets

March 31, 2005 and December 31, 2004

      Assets

2005

2004

(Unaudited)

Current assets:

 Cash 

$         464

705

 Accounts receivable - oil and gas revenues

172,004

263,407

 Due from Managing General Partner

        479

          -    

          Total  current assets

172,947

264,112

Oil and gas properties, successful efforts method

6,952,955

6,952,955

     Less accumulated  depreciation, depletion 

        and amortization

 4,530,429

 4,492,937

 2,422,526

 2,460,018

$ 2,595,473

 2,724,130

     Liabilities and  Partners' Equity

Current liabilities:

 Accrued expenses

$     52,671

   67,624

          Total  current liabilities

52,671

67,624

Asset retirement obligations

33,814

33,314

Partners' Equity

2,508,988

 2,623,192

$2,595,473

 2,724,130

See accompanying notes to financial statements.

1

PDC 1996-D LIMITEDPARTNERSHIP

(A West VirginiaLimited Partnership)

Statements ofOperations

Three Months ended March 31, 2005 and 2004

(Unaudited)

                                                                                                                                                           

     2005

 2004

 

2002

Revenues:

Sales of oil and gas

$ 313,734

 327,274

633,245 

Interest income

       263

       101

 

      593 

313,997

327,375

 

633,838 

Expenses:

Lifting cost

128,268

127,836

386,716 

Direct administration cost

524

-    

223 

Depreciation, depletion, 

 and amortization

 

  37,492

 

  45,573

 

 

 

  197,634 

166,284

173,409

 

  584,573 

Net Income

$ 147,713

153,966

  49,265  

 

 

Net income per limited partner unit

                     $        154

161

 

                

                See accompanying notes to financial statements.

2

PDC 1996-D LIMITEDPARTNERSHIP

(A West VirginiaLimited Partnership)

Statement ofPartners' Equity and Comprehensive Income (Loss)

Three months ended March 31, 2005

(Unaudited)

Limited

Partners

   Managing

General Partner

Accumulated

Other

Comprehensive

Income (loss)

                                        Total

Balance December 31, 2004 

$1,665,995  

980,511 

(23,314)

2,623,192 

Distributions to partners

(212,317)

(53,079)

-    

(265,396)

Comprehensive income:

Net income

118,170 

29,543 

-    

147,713 

Change in fair value of 

  outstanding hedging positions

 

 

78 

 

Less reclassification adjustments   for  settled contracts included in 

  net income

 

 

 

        3,401 

 

Other comprehensive income

3,479 

       3,479 

Comprehensive income

                   

                   

                 

    151,192 

Balance March 31, 2005

$ 1,571,848 

   956,975 

   (19,835)

 2,508,988 

See accompanying notes to financial statements.

3

PDC 1996-D 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 

$147,713 

153,966 

Adjustments to reconcile net income to net cash

  provided from operating activities:

  Depreciation, depletion and amortization

37,492 

45,573 

  Accretion of asset retirement obligations

500 

-     

  Changes in operating assets and  liabilities:

  Decrease (increase) in accounts receivable  - oil and gas revenues

85,738 

(44,530)

 Increase in due from Managing General Partner

(479)

-    

  Decrease in accounts payable 

      (5,809)

      (3,745)

         Net  cash provided from operating activities

    265,155 

     151,264 

Cash flows from financing activities:

  Distributions to partners

 (265,396)

  (151,164)

          Net  cash used by financing activities 

(265,396)

(151,164)

Net (decrease) increase in cash

(241)

100 

Cash at beginning of period

           705 

         3,789 

Cash at end of period

$           464 

         3,889 

See accompanying notes to financial statements.

4

                                                                 PDC 1996-D LIMITED PARTNERSHIP

(A West VirginiaLimited Partnership)

Notes to FinancialStatements

(Unaudited)

1.     AccountingPolicies

        Referenceis hereby made to PDC 1996-D Limited Partnership (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

        ThePartnership follows the successful efforts method of accounting for the cost ofexploring for 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 which willbe determined at year end by Petroleum Development Corporation's (the ManagingGeneral Partner's) petroleum engineer. If a determination is made that anexploratory well has not discovered economically producible reserves, then itscosts are expensed as dry hole costs.  

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.     Revenue Recognition

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 certainadjustments based on, among other factors, whether a well delivers to agathering or transmission line, quality of natural gas and prevailing supplyand demand conditions, so that the price of the natural gas fluctuates toremain competitive 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.

5.    DerivativeFinancial Instruments

The Managing GeneralPartner utilizes commodity based derivative instruments as hedges to manage aportion of the Partnership's exposure to price volatility stemming from naturalgas production. These instruments consist of costless collars and optioncontracts traded on the New York Mercantile Exchange (NYMEX).  The costlesscollars and option contracts hedge committed and anticipated natural gas salesgenerally forecasted to occur within a 24 month period. The partnership doesnot hold or issue derivatives for trading or speculative purposes.

5

PDC 1996-D LIMITEDPARTNERSHIP

(A West VirginiaLimited Partnership)

Notes to FinancialStatements

(Unaudited)

All derivatives arerecognized on the Partnership balance sheet at their fair value. On the datethe derivative contract is entered into, the Managing General Partnerdesignates the derivative as either a hedge of a forecasted transaction or thevariability of cash flows to be received or paid related to a recognized assetor liability ("cash flow" hedge), or a non-hedging derivative. The ManagingGeneral Partner formally documents all relationships between hedginginstruments and hedged items, as well as its risk-management objective andstrategy for undertaking various hedge transactions. This process includeslinking all derivatives that are designated as cash-flow hedges to specificfirm commitments. The Managing General Partner also formally assesses, both atthe hedge's inception and on an ongoing basis, whether the derivatives that areused in hedging transactions are highly effective in offsetting changes in cashflows of hedged items.  When it is determined that a derivative is not highlyeffective as a hedge or that it has ceased to be a highly effective hedge, thePartnership discontinues hedge accounting prospectively. No hedging activitieswere discontinued 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 other comprehensiveincome, until earnings are affected by the variability in cash flows of thedesignated hedged item. Changes in the fair value of non-hedging derivativesare reported in current-period earnings. The Partnership discontinues hedgeaccounting prospectively when it is determined that the derivative is no longereffective in offsetting changes in the cash flows of the hedged item, thederivative expires or is sold, terminated, or exercised.  Additionally, if thederivative is designated as a hedging instrument, because it is probable that aforecasted transaction will not occur, or the Partnership determines thatdesignation of the derivative as a hedging instrument is no longer appropriate,hedge accounting will be discontinued.

By using derivative financial instrumentsto hedge exposures to changes in commodity prices, the Managing General Partnerexposes the Partnership to credit risk. Credit risk is the failure of thecounterparty to perform under the terms of the derivative contract. When thefair value of a derivative contract is positive, the counterparty owes thePartnership, which creates credit risk. The Managing General Partner minimizesthe credit risk in derivative instruments by entering into transactions withhigh-quality counterparties.

Item2.  Management's Discussion and Analysis of Financial Condition and Resultsof Operations

Liquidityand Capital Resources

The Partnership was funded on December 31, 1996 with initial Limited and Additional General Partner contributions of $15,301,726 (765.0863units) and the Managing General Partner's cash contribution of $3,328,126 in accordancewith the Limited Partnership Agreement.  

After payment of syndication costs of $1,606,681 and aone-time management fee to the Managing General Partner of $382,543 thePartnership had available cash of $16,640,628 for Partnership activities.

The Partnershipbegan exploration and development activities subsequent to the funding of thePartnership and completed well drilling activities by December 31, 1997.  Eighty-five wells have been drilled of which eighty have been completed asproducing wells.   No additional wells will be drilled.

ThePartnership had working capital at March 31, 2005 of $120,276.

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

 

 

 

6

PDC 1996-D LIMITEDPARTNERSHIP

(A West VirginiaLimited Partnership)

Notes to FinancialStatements 

(Unaudited)

 

Resultsof Operations
Three months ended March 31, 2005 compared with March 31, 2004
Gassales for the three months ended March 31, 2005 were $313,734 compared to $327,274 for the three months ended March 31, 2004, a decrease of $13,540 or 4.14%.  The volume of natural gas sold for the three months ended March 31, 2005, was 54,015 Mcf at an average sales price of $5.81 per Mcf compared to62,658 Mcf at an average price of $5.22 per Mcf for the three months ended March 31, 2004.  Lifting cost for the three months ended March 31, 2005 was $2.38 per Mcfe compared to $2.04 per Mcfe for the three months ended March 31, 2004.  Depreciation, depletion and amortization decreased from $45,573 for the three monthsended March 31, 2004 to $37,492 for the three months ended March 31, 2005 as a result of lower volumes of natural gas sold.  The Partnership experienced a netincome of $147,713 and $153,966, and distributed $265,396 and $151,164 to thepartners for the three months ended March 31, 2005 and 2004, respectively.

The Partnership's revenue from gas will be affected bychanges in prices.  As a result of changes in federal regulations, gas pricesare highly dependent on the balance between supply and demand.  ThePartnership's oil and gas sales prices are subject to increase and decreasebased on various market sensitive indices.

CriticalAccounting Policies and Estimates  

Certain accounting policies are very important to theportrayal of the Partnership's financial condition and results of operationsand require management's most subjective or complex judgments.  In applyingthose policies, our management uses its judgment to determine the appropriateassumptions to be used in the determination of certain estimates. Thoseestimates are based on our historical experience, our observance of trends inthe 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 rights andresponsibility of ownership pass to the purchaser upon delivery, collection ofrevenue 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.

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.

7

PDC 1996-D LIMITEDPARTNERSHIP

(A West VirginiaLimited Partnership)

Notes to FinancialStatements 

(Unaudited)

 

Oil and Gas Properties 

 

Exploration and development costs are accounted for bythe successful efforts method.

The Partnership assesses impairment of capitalized costsof proved oil and gas properties by comparing net capitalized costs to estimatedundiscounted future net cash flows on a field-by-field basis using expectedprices. 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 flows,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 or leases are written-off to expensewhen it is determined that they will expire or be abandoned.

Costs of proved properties, including leaseholdacquisition, exploration and development costs and equipment, are depreciatedor 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.

RecentlyIssued 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.

 

DisclosureRegarding Forward Looking  Statements

ThisForm 10-Q contains "forward-looking statements" within the meaning of Section27A of the Securities Act of 1933, as amended (the "Securities Act"), andSection 21E of the Securities Exchange Act of 1934, as amended (the "ExchangeAct"). All statements other than statements of historical facts included in andincorporated by reference into

8

PDC 1996-D LIMITEDPARTNERSHIP

(A West VirginiaLimited Partnership)

Notes to FinancialStatements 

(Unaudited)

thisForm 10-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. 

             

Whenused in the Form 10-Q, the words, "expect," "anticipate," "intend," "plan,""believe," "seek," "estimate" and similar expressions are intended to identifyforward-looking statements, although not all forward-looking statements containthese identifying words. Because these forward-looking statements involve risksand uncertainties, actual results could differ materially from those expressedor implied by these forward-looking statements for a number of importantreasons, including those discussed under "Management's Discussions and Analysisof Financial Condition and Results of Operations" and elsewhere in this Form10-Q. 

                                                                         

Item 3.          Quantitative and QualitativeDisclosure About Market Rate Risk

Market-Sensitive Instruments and Risk Management

ThePartnership's primary market risk exposure is commodity price risk.  Thisexposure is discussed in detail below:

Commodity Price Risk

TheManaging General Partner utilizes commodity-based derivative instruments ashedges to manage a portion of its exposure to price risk from its natural gassales.  These instruments consist of NYMEX-traded natural gas futures contractsand option contracts for Appalachian and Michigan 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's exposure to changes in price associated with thehedged commodity, they also limit the benefit the Partnership might otherwisehave received from price changes associated with the hedged commodity.  ThePartnership's policy prohibits the use of natural gas future and optioncontracts for speculative purposes.

     

The following tables summarize the open futures andoptions contracts for the Partnership as of March 31, 2005 and March 31, 200 4.

Commodity

Type

Quantity

Weighted  

Total

Fair

Gas-Mmbtu

Average

Contract

Market

 

 

Oil-Barrels

Price

Amount

Value

Total Contracts as of March 31, 2005

 Natural  Gas

Purchase

433

6.58

2,849

578 

Natural  Gas

Floors

29,843

4.95

-    

1,288 

Natural  Gas

Ceilings

14,922

7.05

-    

(21,701)

Contracts maturing in 12 months following March 31, 2005 

 Natural  Gas

Purchase

433

6.58

2,849

578 

Natural  Gas

Floors

29,843

4.95

-    

1,288 

Natural  Gas

Ceilings

14,922

7.05

-    

(21,698)

9

PDC 1996-D LIMITEDPARTNERSHIP

(A West VirginiaLimited Partnership)

Notes to FinancialStatements 

(Unaudited)

Prior Year Total Contracts as of March 31, 2004

Natural  Gas

Purchase

2,475

4.77

11,804

3,206 

Natural  Gas

Floors

153,976

4.48

-    

-    

Natural  Gas

Ceilings

67,364

5.37

-    

(20,849)

The maximum term over which the Partnership is hedgingexposure to the variability of cash flows for commodity price risk is 12months.      

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 

           (a)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 1996-D 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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