CONFORMED COPY

QUARTERLY REPORT UNDER SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

the Securities Exchange Act of 1934

For the period ended ~~March~~June 3130, 2005

[ ] Transition Report Pursuant to Section 13 of 15(d) of

the Securities Exchange Act of 1934

For the transition period from to

Commission file number 333-47622-01

I.R.S. Employer Identification Number 30-0059674

PDC 2002-A LIMITED PARTNERSHIP

(A West Virginia Limited Partnership)

103 East Main Street

Bridgeport, WV 26330

Telephone: (304) 842-6256

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes XX No

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

PDC 2002-A LIMITED PARTNERSHIP

(A West Virginia Limited Partnership)

INDEX

PART I - FINANCIAL INFORMATION			Page No.
Item 1.1.	Financial Statements
		Balance Sheets - March 31, 2005 (unaudited) and December 31, 2004	1
		Balance Sheets - June 30, 2005 (unaudited) and December 31, 2004	1
		Statements of Operations - Three Months Ended March 31, 2005 and 2004 (unaudited)	2
		Statements of Operations - Three Months and Six Months Ended June 30, 2005 and 2004 (unaudited)	2
		Statement of Partners' Equity and Comprehensive Income (Loss) - Three Months Ended March 31, 2005 (unaudited)	3
		Statement of Partners' Equity and Comprehensive Income (Loss) - Six Months Ended June 30, 2005 (unaudited)	3
		Statements of Cash Flows- Three Months Ended March 31, 2005 and 2004 (unaudited)	4
		Statements of Cash Flows- Six Months Ended June 30, 2005 and 2004 (unaudited)	4
		Notes to Financial Statements	5
		Notes to Financial Statements (unaudited)	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	1112
Item 6.		Exhibits	1112

PDC 2002-A LIMITED PARTNERSHIP

(A West Virginia Limited Partnership)

Balance Sheets

~~March~~June 3130, 2005 and December 31, 2004

Assets
	2005	2004
	(Unaudited)
Current assets:
Cash	$ 23,~~230~~287	2,417
Accounts receivable - oil and gas revenues	~~303~~236,~~565~~332	325,102
Due from managing general partner	453	-
Total current assets	239,619	327,519
Total current assets	306,248	327,519
Oil and gas properties, successful efforts method	7,776,484	7,776,484
Less accumulated depreciation, depletion
and amortization	2,~~067~~141,~~033~~997	1,962,031
	5,709,451	5,814,453
	5,634,487	5,814,453
	$ 6,015,699	6,141,972
	$ 5,874,106	6,141,972
Liabilities and Partners' Equity
Current liabilities:
Accrued expenses	$ 2941,~~840~~471	48,236
Total current liabilities	2941,~~840~~471	48,236
Asset retirement obligations	4,~~297~~361	4,233
Partners' Equity	5,~~981~~828,~~562~~274	6,089,503
	$6,015,699	6,141,972
	$5,874,106	6,141,972

See accompanying notes to financial statements.

-1-

PDC 2002-A LIMITED PARTNERSHIP

(A West Virginia Limited Partnership)

Statements of Operations

Three Months and Six Months ended ~~March~~June 3130, 2005 and 2004

(Unaudited)

	2005	2004
	Three Months Ended June 30		Six Months Ended June30
Revenues:
	2005	2004	2005	2004
Sales of oil and gas	$371,955	471,630
Revenues:
Interest income	266	203
Sales of oil and gas	$ 242,637	372,657	614,592	844,287
	372,221	471,833
Interest income	604	170	870	373
Expenses:
	243,241	372,827	615,462	844,660
Lifting cost	151,848	94,687
Expenses:
Direct administration cost	64	-
Lifting cost	140,498	78,744	292,346	173,431
Depreciation, depletion, and amortization	105,002 256,914	134,483 229,170
Direct administration cost	64	-	128	-
Net income	$ 115,307	242,663
Depreciation, depletion, and amortization	74,964	136,555	179,966	271,038
Net income per limited partner unit	$ 258	543
	215,526	215,299	472,440	444,469
Net income	$ 27,715	157,528	143,022	400,191
Net income per limited partner unit	$ 62	353	320	896

See accompanying notes to financial statements.

-2-

PDC 2002-A LIMITED PARTNERSHIP

(A West Virginia Limited Partnership)

Statement of Partners' Equity and Comprehensive Income (Loss)

~~Three~~Six months ended ~~March~~June 3130, 2005

(Unaudited)

	Limited Partners	Managing General Partner	Accumulated Other Comprehensive Income (loss)	Total
Balance December 31, 2004	$4,884,585	1,221,145	(16,227)	6,089,503
Distributions to partners	(~~174~~309,~~528~~469)	(4377,~~632~~367)	-	(~~218~~386,~~160~~836)
Comprehensive income:
Net income	92114,~~246~~417	2328,~~061~~605	-	~~115~~143,~~307~~022
Change in fair value of outstanding hedging positions			(633,~~304~~255)
Less reclassification adjustments for settled contracts included in net income			115,~~216~~840
Other comprehensive income			(5,088)	(5,088)
Other comprehensive loss			(17,415)	(17,415)
Comprehensive income				~~110~~125,~~219~~607
Balance March 31, 2005	$ 4,802,303	1,200,574	(21,315)	5,981,562
Balance June 30, 2005	$ 4,689,533	1,172,383	(33,642)	5,828,274

See accompanying notes to financial statements.

-3-

PDC 2002-A LIMITED PARTNERSHIP

(A West Virginia Limited Partnership)

Statements of Cash Flows

~~Three~~Six Months ended ~~March~~June 3130, 2005 and 2004

(Unaudited)

	2005	2004
Cash flows from operating activities:
Net income	$~~115~~143,~~307~~022	~~$242~~400,~~663~~191
Adjustments to reconcile net income to net cash
provided from operating activities:
Depreciation, depletion and amortization	~~105~~179,~~002~~966	~~134~~271,~~483~~038
Accretion of asset retirement obligations	64128	-
Changes in operating assets and liabilities:
Decrease in accounts receivable - oil and gas revenues	~~918~~68,354	44141,~~413~~030
Increase in due from managing general partner	(453)	-
Decrease in accounts payable	(3,764)	(2,192)
Decrease in accounts payable	(2,865)	(1,187)
Net cash provided from operating activities	387,706	810,067
Net cash provided from operating activities	217,973	420,372
Cash flows from financing activities:
Distributions to partners	(~~218~~386,~~160~~836)	(~~420~~809,~~169~~743)
Net cash used by financing activities	(~~218~~386,~~160~~836)	(~~420~~809,~~169~~743)
Net (decrease) increase in cash	(187)	203
Net increase in cash	870	324
Cash at beginning of period	2,417	1,742
Cash at end of period	$ 23,~~230~~287	~~$ 1~~2,~~945~~066

See accompanying notes to financial statements.

-4-

PDC 2002-A LIMITED PARTNERSHIP

(A West Virginia Limited Partnership)

Notes to Financial Statements

(Unaudited)

1. Accounting Policies

~~Reference~~The isaccompanying ~~hereby~~condensed ~~made~~interim financial statements and related disclosures are unaudited and have been prepared pursuant to ~~PDC~~U.S. ~~2002-A~~generally ~~Limited~~accepted ~~Partnership's~~accounting principles for interim financial statements and the rules and regulations of the Securities and Exchange Commission (the ~~Partnership's~~Commission). As ~~Annual~~permitted by these ~~Report~~regulations, oncertain ~~Form~~information ~~10-K~~and ~~for~~footnote ~~2004,~~disclosures ~~which~~that ~~contains~~would atypically be ~~summary~~required ofin ~~significant~~annual financial statements have been condensed or omitted. ~~accounting~~However, ~~policies~~management ~~followed~~believes bythat these statements reflect all the ~~Partnership~~normal recurring adjustments necessary for a fair presentation, in all material respects, of the ~~preparation~~results of ~~its~~operations for the periods presented, so that these interim financial statements are not misleading. These ~~policies~~condensed ~~were~~financial statements ~~also~~should ~~followed~~be read in ~~preparing~~conjunction with the financial statements and ~~quarterly~~notes ~~report~~thereto included ~~herein~~in the PDC 2002-A Limited Partnership's (the Partnership) Annual Report on Form 10-K for the year ended December 31, 2004.

2. ~~Basis~~Use of ~~Presentation~~Estimates

~~The~~To ~~Management~~prepare offinancial ~~the~~statements ~~Partnership~~in ~~believes~~accordance ~~that~~with ~~all~~generally ~~adjustments~~accepted ~~(consisting~~accounting principles, ofthe ~~only normal~~Partnership's ~~recurring~~management ~~accruals)~~is ~~necessary~~required to amake ~~fair~~estimates ~~statement~~and assumptions ofthat affect the ~~results~~reported amounts of ~~such periods~~assets ~~have~~and ~~been~~liabilities, ~~made. The~~and disclosure ~~results~~ of ~~operations~~contingent ~~for~~assets ~~the~~and ~~three~~liabilities ~~months~~at ~~ended~~the ~~March~~date ~~31,~~of ~~2005~~the ~~are~~financial statements, ~~not~~and ~~necessarily~~reported ~~indicative~~amounts of revenues and expenses incurred during the reporting period. Actual results tocould bediffer ~~expected~~from ~~for~~those ~~the full year~~estimates.

3. Oil and Gas Properties

The Partnership follows the successful efforts method of accounting for the cost of exploring for and developing oil and gas reserves. Under this method, costs of development wells, including equipment and intangible drilling costs related to both producing wells and developmental dry holes, and successful exploratory wells are capitalized and amortized on an annual basis to operations by the units-of-production method using estimated proved developed reserves determined at year end by Petroleum Development Corporation's (the Managing General Partner's) petroleum engineers. If a determination is made that an exploratory well has not discovered economically producible reserves, then its costs are expensed as dry hole cost.

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

4. Revenue Recognition

Sales of natural gas are recognized when natural gas has been delivered to a custody transfer point, persuasive evidence of a sales arrangement exists, the rights and responsibility of ownership pass to the purchaser upon delivery, collection of revenue from the sale is reasonably assured and the sales price is fixed or determinable. Natural gas is sold by the Managing General Partner under contracts with terms ranging from one month to three years. Virtually all of the Managing General Partner's contracts pricing provisions are tied to a market index, with certain adjustments based on, among other factors, whether a well delivers to a gathering or transmission line, quality of natural gas and prevailing supply and demand conditions, so that the price of the natural gas fluctuates to remain competitive with other available natural gas supplies. As a result, the Partnership's revenues from the sale of natural gas will suffer if market prices decline and benefit if they increase. The Partnership believes that the pricing provisions of its natural gas contracts are customary in the industry.

The Managing General Partner currently uses the "Net-Back" method of accounting for transportation arrangements of natural gas sales. The Managing General Partner sells gas at the wellhead and collects a price and recognizes revenues based on the wellhead sales price since transportation costs downstream of the wellhead are incurred by the Managing General Partner's customers and reflected in the wellhead price.

Sales of 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 of revenue from the sale is reasonably assured and the sales price is determinable. The Partnership is currently able to sell all the oil that it can produce under existing sales contracts with petroleum refiners and marketers. The Partnership does not refine any of its oil production. The Partnership's crude oil production is sold to purchasers at or near the Partnership's wells under short-term purchase contracts at prices and in accordance with arrangements that are customary in the oil industry.

-5-

PDC 2002-A LIMITED PARTNERSHIP

(A West Virginia Limited Partnership)

Notes to Financial Statements

(Unaudited)

5. Derivative Financial Instruments

The Managing General Partner utilizes commodity based derivative instruments as hedges to manage a portion of the Partnership's exposure to price volatility stemming from natural gas and oil production. These instruments consist of CIG (Colorado Interstate ~~Gas~~ Gas Index) based contracts for Colorado production, and NYMEX (New York Mercantile Exchange) traded oil futures and option contracts for Colorado oil production. The costless collars and option contracts hedge committed and anticipated oil and natural gas sales generally forecasted to occur within a 24 month period. The Partnership does not hold or issue derivatives for trading or speculative purposes.

All derivatives are recognized on the Partnership's balance sheet at their fair value. On the date the derivative contract is entered into, the Managing General Partner designates the derivative as ~~either~~ a hedge of a forecasted transaction ~~or the~~(future ~~variability~~production ofand ~~cash~~sales ~~flows~~of tooil beand ~~received~~gas) ~~or paid related to a recognized asset or liability~~ ("cash flow" hedge), or a non-hedging derivative. The Managing General Partner formally documents all relationships between hedging instruments and hedged items, as well as its risk-management objective and strategy for undertaking various hedge transactions. This process ~~includes~~ includes linking all derivatives that are designated as cash-flow hedges to ~~specific~~ specific firm commitments. The Managing General Partner also formally assesses, both at the hedge's inception and on an ongoing basis, whether the derivatives that are used in hedging transactions are highly effective in offsetting changes in cash flows of hedged items. When it is determined that a derivative is not highly effective as a hedge or that it has ceased to be a highly effective hedge, the Partnership discontinues hedge accounting prospectively. No hedging activities were discontinued during 2005 or 2004.

Changes in fair value of a derivative that is highly effective and that is designated and qualifies as a cash-flow hedge are recorded in accumulated other comprehensive income, until earnings are affected by the variability in cash flows of the designated hedged item. Changes in the fair value of non-hedging derivatives are reported in current-period earnings. The Partnership discontinues hedge accounting prospectively when it is determined that the derivative is no longer effective in offsetting changes in the cash flows of the hedged item, the derivative expires or is sold, terminated, or exercised. Additionally, if the derivative is designated as a hedging instrument, because it is probable that a forecasted transaction will not occur, or the Partnership determines that designation of the derivative as a hedging instrument is no longer appropriate, hedge accounting will be discontinued.

By using derivative financial instruments to hedge exposures to changes in commodity prices, the Managing General Partner exposes the Partnership to credit risk. Credit risk is the failure of the counterparty to perform under the terms of the derivative contract. When the fair value of a derivative contract is positive, the counterparty owes the Partnership, which creates credit risk. The Managing General Partner minimizes the credit risk in derivative instruments by entering into transactions with high-quality counterparties.

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

Liquidity and Capital Resources

The Partnership was funded on April 30, 2002 with initial Limited and Additional General Partner contributions of $7,147,522 (357.38 units) and the Managing General Partner's cash contribution of $1,554,586 in accordance with the Limited Partnership Agreement. After payment of syndication costs of $750,490 and a one-time management fee to the Managing General Partner of $178,688 the Partnership had available cash of $7,772,930 for Partnership activities.

The Partnership began exploration and development activities subsequent to the funding of the Partnership and completed well drilling activities by December 31, 2002. Ten wells have been drilled, all of which have been completed as producing wells. No additional wells will be drilled.

The Partnership had working capital at March 31, 2005 of $276,408.

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

-6-

PDC 2002-A LIMITED PARTNERSHIP

(A West Virginia Limited Partnership)

Notes to Financial Statements

(Unaudited)

The Partnership had working capital at June 30, 2005 of $198,148.

Operations are expected to be conducted with available funds and revenues generated from oil and gas activities. Under the Limited Partnership Agreement, the Partnership is not permitted to borrow funds.

Results of Operations

Three months ended June 30, 2005 compared with June 30, 2004 Oil and gas sales for the three months ended ~~March~~June 30, 2005 were $242,637 compared to $372,657 for the three months ended June 30, 2004, a decrease of $130,020 or 34.9%. The volume of natural gas sold for the three months ended June 30, 2005, was 36,004 Mcf at an average sales price of $5.27 per Mcf compared to 83,992 Mcf at an average price of $3.88 per Mcf for the three months ended June 30, 2004. The volume of oil sold for the three months ended June 30, 2005 was 1,147 barrels at an average sales price of $46.18 compared to 1,330 barrels at an average price of $35.31 for the three months ended June 30, 2004. The lifting cost for the three months ended June 30, 2005 was $3.28 per Mcfe compared to $0.85 per Mcfe for the three months ended June 30, 2004. This increase is partially attributed to the increase in severance and property taxes along with ~~March~~costs 31associated with workovers. The fixed costs of operations and well maintenance are allocated to lower production volumes, therefore increasing the lifting cost per Mcfe. Depreciation, depletion and amortization for the three months ended June 30, 2005 was $74,964 compared to $136,555 for the three months ended June 30, 2004. The Partnership experienced a net income of $27,715 and $157,528 and distributed $168,676 and $389,574 to the partners for the three months ended June 30, 2005 and 2004, respectively.

~~Oil~~Six ~~and~~Months ~~gas sales for the three months~~ ended ~~March~~June 3130, 2005 ~~were $371,955~~ compared towith ~~$471,630~~June ~~for the three months ended March 31~~30, 2004, a decrease of $99,675 or 21.1%. The volume of natural gas sold for the three months ended March 31, 2005, was 47,687 Mcf at an average sales price of $5.84 per Mcf compared to 92,963 Mcf at an average price of $4.67 per Mcf for the three months ended March 31, 2004. The volume of oil sold for the three months ended March 31, 2005 was 2,064 barrels at an average sales price of $45.24 compared to 1,207 barrels at an average price of $31.11 for the three months ended March 31, 2004. The Lifting cost for the three months ended March 31, 2005 was $2.53 per Mcfe compared to $0.94 per Mcfe for the three months ended March 31, 2004. This increase is partially attributed to the increase in severance, property taxes and workovers. The fixed costs of operations and well maintenance are allocated to lower production volumes, therefore increasing the lifting cost per Mcfe. Depreciation, depletion and amortization for the three months ended March 31, 2005 was $105,002 compared to $134,483 for the three months ended March 31, 2004. The Partnership experienced a net income of $115,307 and distributed $218,160 to the partners for the three months ended March 31, 2005.

~~The~~Oil and ~~Partnership's~~gas ~~revenue~~sales ~~from~~for ~~oil~~the ~~and~~six months ended June 30, 2005 were $614,592 compared to $844,287 for the six months ended June 30, 2004 a decrease of $229,695 or 27.2%. The volume of natural gas ~~will~~sold befor the six months ended June 30, 2005, was 83,691 Mcf at an average sales price of $5.59 per Mcf compared to 176,955 Mcf at ~~affected~~an byaverage ~~changes~~price inof ~~prices~~$4.29 per Mcf for the six months ended June 30, 2004. AsThe avolume ~~result~~of oil sold for the six months ended June 30, 2005 was 3,211 barrels at an average sales price of ~~changes~~$45.58 incompared ~~federal~~to ~~regulations~~2, ~~gas~~537 ~~prices~~barrels ~~are~~at ~~highly~~an ~~dependent~~average price onof $33.31 for the ~~balance~~six ~~between~~months ~~supply~~ended ~~and~~June ~~demand~~30, 2004. The lifting cost for the six months ended June 30, 2005 was $2.84 per Mcfe compared to $.90 ~~Partnership's~~per ~~oil~~Mcfe for the six months ended June 30, 2004. The increase is partially attributed to the increase in severance and ~~gas~~property ~~sales~~taxes ~~prices~~along with costs associated with workovers. The fixed costs of operations and well maintenance are ~~subject~~allocated to ~~increase~~lower production volumes therefore increasing the lifting cost per Mcfe. The Partnership experienced a net income of $143,022 and ~~decrease~~$400,191and ~~based~~distributed on$386,836 ~~various~~and ~~market~~$809,743 ~~sensitive~~to ~~indices~~the partners for the six months ended June 30, 2005 and 2004, respectively.

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

~~Certain accounting policies are very important~~Critical toAccounting the portrayal of the Partnership's financial condition and results of operations and require management's most subjective or complex judgments. In applying those policies, our management uses its judgment to determine the appropriate assumptions to be used in the determination of certain estimates. Those estimates are based on our historical experience, our observance of trends in the industry, and information available from other outside sources, as appropriate. The Partnership's critical accounting policies and estimates are as follows:Policies

~~Revenue~~ Certain ~~Recognition. Sales~~accounting ofpolicies ~~natural gas~~ are ~~recognized when~~very ~~natural gas has been delivered~~ important to athe ~~custody~~portrayal ~~transfer point, persuasive evidence~~ of athe ~~sales~~Partnership's ~~arrangement~~financial ~~exists,~~condition ~~the rights~~ and ~~responsibility~~results of ~~ownership~~operations ~~pass to the purchaser upon delivery, collection of revenue from the sale is reasonably assured~~ and ~~the~~require ~~sales~~management's ~~price~~most issubjective ~~fixed~~ or ~~determinable~~complex judgments. In ~~Natural~~applying ~~gas~~those ispolicies, ~~sold~~our bymanagement ~~the~~uses ~~Managing~~its ~~General~~judgment ~~Partner~~to ~~under~~determine ~~contracts with terms~~the ~~ranging~~appropriate ~~from~~assumptions ~~one~~to ~~month~~be toused ~~three~~in ~~years. Virtually~~the ~~all~~determination of ~~the~~certain ~~Managing General~~estimates. ~~Partner's~~Those ~~contracts~~estimates ~~pricing provisions~~ are ~~tied to a market index, with certain adjustments~~ based on, ~~among~~our ~~other~~historical ~~factors~~experience, ~~whether~~our aobservance ~~well delivers to a~~of ~~gathering~~trends orin ~~transmission~~the ~~line~~industry, ~~quality of natural gas~~ and ~~prevailing~~information ~~supply and~~available ~~demand~~from ~~conditions,~~other sooutside ~~that the price of the natural gas fluctuates to~~sources, ~~remain~~as ~~competitive with other available natural gas supplies~~appropriate. As aThe ~~result, the~~ Partnership's ~~revenues~~critical ~~from~~accounting ~~the~~policies ~~sale of natural gas will suffer if market prices decline~~ and ~~benefit if they increase. The Partnership believes that the~~estimates ~~pricing provisions of its natural gas contracts~~ are ~~customary~~as ~~in the industry.~~follows:

~~The Managing General Partner currently uses the "Net~~-Back" method of accounting for transportation arrangements of natural gas sales. The Managing General Partner sells gas at the wellhead and collects a price and recognizes revenues based on the wellhead sales price since transportation costs downstream of the wellhead are incurred by the Managing General Partner's customers and reflected in the wellhead price.7-

~~Sales of~~PDC 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 of revenue from the sale is reasonably assured and the sales price is determinable. The Partnership is currently able to sell all the oil that it can produce under existing sales contracts with petroleum refiners and marketers. The Partnership does not refine any of its oil production. The Partnership's crude oil production is sold to purchasers at or near the Partnership's wells under short2002-~~term~~A ~~purchase contracts at prices and in~~LIMITED ~~accordance with arrangements that are customary in the oil industry.~~ PARTNERSHIP

~~-7-~~(A West Virginia Limited Partnership)

~~PDC~~Notes ~~2002-A~~to ~~LIMITED~~Financial ~~PARTNERSHIP~~Statements

(~~A West Virginia Limited Partnership~~Unaudited)

~~Notes~~Revenue Recognition. Sales of natural gas are recognized when natural gas has been delivered to ~~Financial~~a custody transfer point, persuasive ~~Statements~~evidence of a sales arrangement exists, the rights and responsibility of ownership pass to the purchaser upon delivery, collection of revenue from the sale is reasonably assured and the sales price is fixed or determinable. Natural gas is sold by the Managing General Partner under contracts with terms ranging from one month to three years. Virtually all of the Managing General Partner's contracts pricing provisions are tied to a market index, with certain adjustments based on, among other factors, whether a well delivers to a gathering or transmission line, quality of natural gas and prevailing supply and demand conditions, so that the price of the natural gas fluctuates to remain competitive with other available natural gas supplies. As a result, the Partnership's revenues from the sale of natural gas will suffer if market prices decline and benefit if they increase. The Partnership believes that the pricing provisions of its natural gas contracts are customary in the industry.

~~(Unaudited)~~The Managing General Partner currently uses the "Net-Back" method of accounting for transportation arrangements of natural gas sales. The Managing General Partner sells gas at the wellhead and collects a price and recognizes revenues based on the wellhead sales price since transportation costs downstream of the wellhead are incurred by the Managing General Partner's customers and reflected in the wellhead price.

~~Impairment~~ Sales of ~~Long-Lived~~oil ~~Assets~~are ~~The~~recognized ~~Partnership assesses~~when ~~impairment~~persuasive evidence of ~~capitalized~~a ~~costs~~sales ofarrangement ~~proved~~exists, the oil is verified as produced and ~~gas~~is ~~properties~~delivered byin a stock tank, collection of ~~comparing~~revenue ~~net~~from ~~capitalized~~the ~~costs~~sale tois ~~undiscounted~~reasonably ~~future~~assured ~~cash~~and ~~flows~~the onsales aprice is ~~field-by-field~~determinable. The ~~basis~~Partnership ~~using~~is ~~expected~~currently ~~prices.~~able ~~Prices~~to ~~utilized~~sell inall ~~each~~the ~~year's~~oil that it ~~calculation~~can ~~for~~produce ~~measurement~~under ~~purposes~~existing ~~and~~sales ~~expected~~contracts ~~costs~~with ~~are~~petroleum ~~held~~refiners ~~constant~~and ~~throughout~~marketers. The ~~the~~Partnership ~~life~~does not refine any of ~~the~~its ~~properties~~oil production. The Partnership's Ifcrude ~~net~~oil ~~capitalized~~production ~~costs~~is ~~exceed undiscounted~~sold ~~future~~to ~~net~~purchasers ~~cash~~at ~~flow,~~or near the ~~measurement~~Partnership's wells ofunder ~~impairment~~short-term ispurchase ~~based~~contracts ~~on estimated~~at ~~fair~~prices ~~value~~and ~~which~~in ~~would~~accordance ~~consider~~with arrangements ~~future~~that ~~discounted~~are ~~cash~~customary ~~flows~~in the oil industry.

~~Oil~~Impairment of Long-Lived Assets The Partnership assesses impairment of capitalized costs of proved oil and ~~Gas~~gas ~~Properties~~properties by comparing net capitalized costs to undiscounted future cash flows on a field-by-field basis using expected prices. Prices utilized in each year's calculation for measurement purposes and expected costs are held constant throughout the life of the properties. If net capitalized costs exceed undiscounted future net cash flow, the measurement of impairment is based on estimated fair value which would consider future discounted cash flows.

~~Exploration~~Oil and ~~development~~ ~~costs~~Gas ~~are~~Properties ~~accounted for by the successful efforts method.~~

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

Property acquisition costs are capitalized when incurred. Geological and geophysical costs and delay rentals are expensed as incurred. The costs of drilling exploratory wells are capitalized pending ~~determination~~ determination of whether the wells have discovered economically producible reserves. If reserves are not discovered, such costs are expensed as dry holes. Development costs, including equipment and intangible drilling costs related to both producing wells and developmental dry holes are capitalized.

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

Costs of proved properties, including leasehold acquisitions, exploration and development costs and equipment, are depreciated and depleted by the unit-of-production method based on estimated proved developed oil and gas reserves.

Upon sale or retirement of complete fields of depreciable or 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, the proceeds are credited to accumulated depreciation and depletion.

~~Recently Issued Accounting Pronouncements~~-8-

~~Asset Retirement~~PDC ~~Obligations~~2002-A LIMITED PARTNERSHIP

~~On March 30, 2005, the FASB issued FASB Interpretation No. 47, "Accounting for Conditional Asset Retirement Obligations"~~ (~~FIN~~A ~~No.~~West ~~47). This interpretation~~Virginia ~~clarifies~~Limited that the term "conditional asset retirement obligation" as used in Statement No. 143 refers to a legal obligation to perform an asset retirement activity in which the timing and/or method of settlement are conditional on a future event that may or may not be within the control of the entity incurring the obligation. The obligation to perform the asset retirement activity is unconditional even though uncertainty exists about the timing and/or method of settlement. Thus, the timing and/or method of settlement may be conditional on a future event. Accordingly, an entity is required to recognize a liability for the fair value of a conditional asset retirement obligation if the fair value of the liability can be reasonably estimated. Uncertainty about the timing and/or method of settlement of a conditional asset retirement obligation should be factored into the measurement of the liability, rather than the timing of recognition of the liability, when sufficient information exists. FIN No. 47 will 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's financial position or results of operations of the application of FIN No. 47.~~)

~~-8-~~Notes to Financial Statements

~~PDC 2002-A LIMITED PARTNERSHIP~~(Unaudited)

~~(A West Virginia~~Recently ~~Limited~~Issued ~~Partnership)~~Accounting Pronouncements

~~Notes to Financial~~Asset ~~Statements~~Retirement Obligations

On March 30, 2005, the FASB issued FASB Interpretation No. 47, "Accounting for Conditional Asset Retirement Obligations" (~~Unaudited~~FIN No. 47). This interpretation clarifies that the term "conditional asset retirement obligation" as used in Statement No. 143 refers to a legal obligation to perform an asset retirement activity in which the timing and/or method of settlement are conditional on a future event that may or may not be within the control of the entity incurring the obligation. The obligation to perform the asset retirement activity is unconditional even though uncertainty exists about the timing and/or method of settlement. Thus, the timing and/or method of settlement may be conditional on a future event. Accordingly, an entity is required to recognize a liability for the fair value of a conditional asset retirement obligation if the fair value of the liability can be reasonably estimated. Uncertainty about the timing and/or method of settlement of a conditional asset retirement obligation should be factored into the measurement of the liability, rather than the timing of recognition of the liability, when sufficient information exists. FIN No. 47 will be effective for the Partnership at the end of the fiscal year ended December 31, 2005. The Partnership has not yet determined the final impact on the Partnership's financial position or results of operations of the application of FIN No. 47, however the Partnership does expect to record an unfavorable cumulative effect of change in accounting principle within the statement of operations before year end. Such effect may be material to the financial statements.

Disclosure Regarding Forward Looking Statements

This Form 10-Q contains "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933, as amended (the "Securities Act"), and Section 21E of the Securities Exchange Act of 1934, as amended (the "Exchange Act"). All statements other than statements of historical facts included in and incorporated by reference into this Form 10-Q are forward-looking statements. These forward-looking statements are subject to certain risks, trends and uncertainties that could cause actual results to differ materially from those projected. Among those risks, trends and uncertainties are the Managing General Partner's estimate of the sufficiency of its existing capital sources, its ability to raise additional capital to fund cash requirements for future operations, the uncertainties involved in estimating quantities of proved oil and natural gas reserves, in prospect development and property acquisitions and in projecting future rates of 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 the various reports the Partnership has filed with the Securities and Exchange Commission. The Partnership undertakes no duty to update or revise these forward-looking statements.

When used in the Form 10-Q, the words, "expect," "anticipate," "intend," "plan," "believe," "seek," "estimate" and similar 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 these forward-looking statements for a number of important reasons, including those discussed under "Management's Discussions and Analysis of Financial Condition and Results of Operations" and elsewhere in this Form 10-Q.

Item 3. Quantitative and Qualitative Disclosure About Market ~~Rate~~ Risk

Market-Sensitive Instruments and Risk Management

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

~~Commodity Price Risk~~-9-

~~The Managing~~PDC ~~General Partner utilizes commodity~~2002-~~based~~A ~~derivative instruments as~~LIMITED hedges to manage a portion of its exposure to price risk from its oil and natural gas sales. These instruments consist of CIG-based contracts traded by JP Morgan for Colorado production. These hedging arrangements have the effect of locking in for specified periods (at predetermined prices or ranges of prices) the prices the Managing General Partner will receive for the volume to which the hedge relates. As a result, while these hedging arrangements are structured to reduce Partnership's exposure to changes in price associated with the hedged commodity, they also limit the benefit the Partnership might otherwise have received from price changes associated with the hedged commodity. The Partnership's policy prohibits the use of oil and natural gas future and option contracts for speculative purposes.PARTNERSHIP

~~The~~(A ~~following~~West ~~tables summarize the open futures and~~Virginia ~~options~~Limited ~~contracts for the~~ Partnership ~~as of March 31, 2005 and March 31, 200 4.~~)

	Type	Quantity	Weighted	Total	Fair
		Gas-Mmbtu	Average	Contract	Market
		Oil-Barrels	Price	Amount	Value
Total Contracts as of March 31, 2005
Natural Gas	Floors	29,050	4.19	-	773
Natural Gas	Ceilings	14,525	6.69	-	(15,962)
Oil	Floors	741	32.30	23,941	24
Oil	Ceilings	371	40.00	14,824	(6,150)
-9- PDC 2002-A LIMITED PARTNERSHIP (A West Virginia Limited Partnership) Notes to Financial Statements (Unaudited) Contracts maturing in 12 months following March 31, 2005
Natural Gas	Floors	21,318	4.07	-	314
Natural Gas	Ceilings	10,659	6.48	-	(14,399)
Oil	Floors	741	32.30	23,941	24
Oil	Ceilings	371	40.00	14,824	(6,150)
Prior Year Total Contracts as of March 31, 2004
Natural Gas	Floors	36,242	3.45	-	-
Natural Gas	Ceilings	18,121	4.59	-	(5,808)
Oil	Sales	1,786	31.63	56,491	(2,348)

Notes to Financial Statements

~~The maximum term over which the Partnership is hedging exposure to the variability of cash flows for commodity price risk is 19 months.~~ (Unaudited)

~~Disclosure~~Commodity ofPrice ~~Limitations~~Risk

AsThe Managing ~~the~~General ~~information~~Partner ~~above~~utilizes ~~incorporates~~commodity-based ~~only~~derivative ~~those~~instruments as ~~exposures~~hedges ~~that~~to ~~exist~~manage ata ~~March~~portion ~~31,~~of ~~2005,~~its itexposure ~~does~~to ~~not~~price ~~consider~~risk ~~those~~from ~~exposures~~its oroil and ~~positions~~natural ~~which~~gas ~~could~~sales. These ~~arise~~instruments ~~after~~consist ~~that~~of ~~date~~CIG-based contracts traded by JP Morgan for Colorado production. These hedging arrangements have the effect of locking in for specified periods (at predetermined prices or ranges of prices) the prices the Managing General Partner will receive for the volume to which the hedge relates. As a result, ~~the~~while these hedging arrangements are structured to reduce Partnership's exposure ~~ultimate~~to ~~realized~~changes ~~gain~~in orprice ~~loss~~associated with ~~respect~~the tohedged commodity, ~~price~~they ~~fluctuations will~~also ~~depend~~limit onthe benefit the ~~exposures~~Partnership ~~that~~might ~~arise~~otherwise ~~during~~have ~~the~~received ~~period,~~from price changes associated with the hedged commodity. The Partnership's ~~hedging~~ ~~strategies~~policy atprohibits the use ~~time~~of oil and ~~commodity~~natural ~~prices~~gas atfuture ~~the~~and ~~time~~option contracts for speculative purposes.

~~Item~~The ~~4. Controls~~following tables summarize the open futures and options ~~Procedures~~contracts for the Partnership as of June 30, 2005 and June 30, 200 4.

Under the supervision and with the participation of the Managing General Partner's management, including the Managing General Partner's Chief Executive Officer and Chief Financial Officer, the Managing General Partner has evaluated the effectiveness of the design and operation of its disclosure 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 Chief Executive Officer and Chief Financial Officer have concluded that these disclosure controls and procedures are effective in all material respects, including those to ensure that information required to be disclosed in reports filed or submitted under the Securities Exchange Act is recorded, processed, summarized, and reported, within the time periods specified in the Commission's rules and forms, and is accumulated and communicated to management, including the Managing General Partner's Chief Executive Officer and Chief Financial Officer, as appropriate to allow for timely disclosure. There have been no significant changes in our internal control over financial reporting or in other factors that have materially affected or are reasonably likely to materially affect these controls that occurred during the Partnership's last fiscal quarter and subsequent to the date of their evaluation.

	Type	Quantity Gas-Mmbtu Oil-Barrels	Weighted Average Price	Total Contract Amount	Fair Market Value


Total Contracts as of June 30, 2005
Natural Gas	Floors	45,722	$ 4.27	-	$ 993
Natural Gas	Ceilings	22,861	$ 6.83	-	$(17,643)
Oil	Floors	1,868	$32.30	$60,325	$ 8
Oil	Ceilings	934	$40.00	$37,353	$(17,000)
Contracts maturing in 12 months following June 30, 2005
Natural Gas	Floors	36,844	$ 4.22	-	$ 633
Natural Gas	Ceilings	18,422	$ 6.72	-	$(15,288)
Oil	Floors	1,868	$32.30	$60,325	$ 8
Oil	Ceilings	934	$40.00	$37,353	$(17,000)
Prior Year Total Contracts as of June 30, 2004
Natural Gas	Floors	132,605	$ 3.90	-	-
Natural Gas	Ceilings	66,302	$ 5.01	-	$(29,875)
Oil	Sales	1,115	$31.62	$35,257	$ (6,133)

~~-10-~~The maximum term over which the Partnership is hedging exposure to the variability of cash flows for commodity price risk is 16 months.

~~CONFORMED~~Disclosure ~~COPY~~of Limitations

~~PART~~As IIthe -information ~~OTHER~~above incorporates only those ~~INFORMATION~~exposures that exist at June 30, 2005, it does not consider those exposures or positions which could arise after that date. As a result, the Partnership's ultimate realized gain or loss with respect to commodity price fluctuations will depend on the exposures that arise during the period, the Partnership's hedging strategies at the time and commodity prices at the time.

Item 1 4. ~~Legal~~ Controls ~~Proceedings~~and Procedures

~~None.~~Under the supervision and with the participation of the Managing General Partner's management, including the Managing General Partner's Chief Executive Officer and Chief Financial Officer, the Managing General Partner has evaluated the effectiveness of the design and operation of its disclosure controls and procedures (as defined in Exchange

~~Item 6. Exhibits~~ -10-

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

PDC 2002-A LIMITED PARTNERSHIP

~~SIGNATURES~~(A West Virginia Limited Partnership)

~~Pursuant~~Notes to ~~the requirements of the Securities~~Financial ~~Exchange Act of 1934 the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.~~Statements

	PDC 2002-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

(Unaudited)

Act Rule 13a-~~11-~~15(e)) as of the end of this fiscal quarter, and, based on their evaluation, the Chief Executive Officer and Chief Financial Officer have concluded that these disclosure controls and procedures are effective in all material respects, including those to ensure that information required to be disclosed in reports filed or submitted under the Securities Exchange Act is recorded, processed, summarized, and reported, within the time periods specified in the Commission's rules and forms, and is accumulated and communicated to management, including the Managing General Partner's Chief Executive Officer and Chief Financial Officer, as appropriate to allow for timely disclosure. There have been no significant changes in our internal control over financial reporting or in other factors that have materially affected or are reasonably likely to materially affect these controls that occurred during the Partnership's last fiscal quarter and subsequent to the date of their evaluation.

-11-

CONFORMED COPY

PART II - OTHER INFORMATION

Item 1 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 Securities Exchange Act of 1934 the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

	PDC 2002-A Limited Partnership (Registrant) By its Managing General Partner Petroleum Development Corporation


Date: July 22, 2005	/s/ Steven R. Williams Steven R. Williams Chief Executive Officer


Date: July 22, 2005	/s/ Darwin L. Stump Darwin L. Stump Chief Financial Officer

-12-

Filing Compare · Colorado 2002A Limited Partnership