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 ~~June~~March 3031, ~~2004~~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 - June 30, 2004 (unaudited) and December 31, 2003	1
		Balance Sheets - March 31, 2005 (unaudited) and December 31, 2004	1
		Statements of Operations - Three Months and Six Months Ended June 30, 2004 and 2003 (unaudited)	2
		Statements of Operations - Three Months Ended March 31, 2005 and 2004 (unaudited)	2
		Statement of Partners' Equity - Six Months Ended June 30, 2004 (unaudited)	3
		Statement of Partners' Equity and Comprehensive Income (Loss) - Three Months Ended March 31, 2005 (unaudited)	3
		Statements of Cash Flows- Six Months Ended June 30, 2004 and 2003 (unaudited)	4
		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	79
Item 4.		Controls and Procedures	810
PART II OTHER INFORMATION
Item 1.		Legal Proceedings	911
Item 6.		Exhibits ~~and Reports on Form 8-K~~	911

PDC 2002-A LIMITED PARTNERSHIP

(A West Virginia Limited Partnership)

Balance Sheets

~~June~~March 3031, ~~2004~~2005 and December 31, ~~2003~~2004

Assets
	2004	2003
	2005	2004
	(Unaudited)
Current assets:
Cash	$ 2,~~066~~230	12,~~742~~417
Accounts receivable - oil and gas revenues	~~309~~303,~~217~~565	~~450~~325,~~247~~102
Total current assets	311,283	451,989
Due from managing general partner	453	-
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	12,~~662~~067,~~371~~033	1,~~391~~962,~~333~~031
	6,114,113	6,385,151
	5,709,451	5,814,453
	$ 6,425,396	6,837,140
	$ 6,015,699	6,141,972
Liabilities and Partners' Equity
Current liabilities:
Accrued expenses	$ 4429,~~932~~840	1248,~~390~~236
Total current liabilities	4429,~~932~~840	1248,~~390~~236
Asset retirement obligations	34,~~994~~297	34,~~994~~233
Partners' Equity	65,~~376~~981,~~470~~562	6,~~820~~089,~~756~~503
	$6,425,396	6,837,140
	$6,015,699	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 ~~June~~March 3031, ~~2004~~2005 and ~~2003~~2004

(Unaudited)

Three Months Ended June 30, Six Months Ended June 30,

	2005	2004
Revenues:
Sales of oil and gas	$371,955	471,630
Interest income	266	203
	372,221	471,833
Expenses:
Lifting cost	151,848	94,687
Direct administration cost	64	-
Depreciation, depletion, and amortization	105,002 256,914	134,483 229,170

Net income	$ 115,307	242,663
Net income per limited partner unit	$ 258	543

	2004	2003	2004	2003
Revenues:
Sales of oil and gas	$ 372,657	596,001	844,287	1,388,045
Interest income	170	292	373	427
	372,827	596,293	844,660	1,388,472
Expenses:
Lifting cost	78,744	109,008	173,431	238,767
Direct administration cost	-	156	-	213
Depreciation, depletion, and amortization	136,555	274,351	271,038	593,649
	215,299	385,515	444,469	832,629
Net income before cumulative effect of change in accounting principle	157,528	212,778	400,191	555,843
Cumulative effect of change in accounting principle	-	-	-	(392)
Net income	$ 157,528	212,778	400,191	555,451
Net income per limited partner unit before cumulative effect of change in accounting principle	$ 353	476	896	1,244
Cumulative effect of change in accounting principle	-	-	-	(1)
Net income per limited partner unit	$ 353	$ 476	$ 896	$ 1,243

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)

~~Six~~Three ~~Months~~months ended ~~June~~March 3031, ~~2004~~2005

(Unaudited)

	Limited Partners	Managing General Partner	Accumulated Other Comprehensive Income (loss)	Total
Balance December 31, 2003	$5,457,625	1,364,405	(1,274)	6,820,756
Balance December 31, 2004	$4,884,585	1,221,145	(16,227)	6,089,503
Distributions to partners	(~~647~~174,~~794~~528)	(~~161~~43,~~949~~632)	-	(~~809~~218,~~743~~160)
Comprehensive income:
Net income	~~320~~92,~~153~~246	8023,~~038~~061	-	~~400~~115,~~191~~307
Change in fair value of outstanding hedging positions			(216,~~947~~304)
Less reclassification adjustments for settled contracts included in net income			~~(12~~1,~~787)~~216
Other comprehensive loss			(34,734)	(34,734)
Other comprehensive income			(5,088)	(5,088)
Comprehensive income				~~365~~110,~~457~~219
Balance June 30, 2004	$ 5,129,984	1,282,494	(36,008)	6,376,470
Balance March 31, 2005	$ 4,802,303	1,200,574	(21,315)	5,981,562

See accompanying notes to financial statements.

-3-

PDC 2002-A LIMITED PARTNERSHIP

(A West Virginia Limited Partnership)

Statements of Cash Flows

~~Six~~Three Months ended ~~June~~March 3031, ~~2004~~2005 and ~~2003~~2004

(Unaudited)

	2004	2003
	2005	2004
Cash flows from operating activities:
Net income	$~~400~~115,~~191~~307	~~555~~$242,~~451~~663
Adjustments to reconcile net income to net cash
provided from operating activities:
Depreciation, depletion and amortization	~~271~~105,~~038~~002	~~593~~134,~~649~~483
Cumulative effect of change in accounting principle	-	392
Accretion of asset retirement obligations	64	-
Accretion of asset retirement obligations	-	57
Changes in operating assets and liabilities:
Decrease (increase) in accounts receivable - oil and gas revenues	141,030	(171,330)
Decrease in accounts receivable - oil and gas revenues	918	44,413
Decrease in accrued expenses	(2,192)	(6,371)
Increase in due from managing general partner	(453)	-
Net cash provided from operating activities	810,067	971,848
Decrease in accounts payable	(2,865)	(1,187)
Net cash provided from operating activities	217,973	420,372
Cash flows from financing activities:
Distributions to partners	(~~809~~218,~~743~~160)	(~~977~~420,~~446~~169)
Net cash used by financing activities	(~~809~~218,~~743~~160)	(~~977~~420,~~446~~169)
Net increase (decrease) in cash	324	(5,598)
Net (decrease) increase in cash	(187)	203
Cash at beginning of period	12,~~742~~417	61,~~700~~742
Cash at end of period	$ 2,~~066~~230	$ 1,~~102~~945

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 is hereby made to PDC 2002-A Limited Partnership's (the Partnership's) Annual Report on Form 10-K for ~~2003~~2004, which contains a summary of significant accounting policies followed by the Partnership in the preparation of its financial statements. These policies were also followed in preparing the quarterly report included herein.

2. Basis of Presentation

The Management of the Partnership believes that all adjustments (consisting of only normal recurring accruals) necessary to a fair statement of the results of such periods have been made. The results of operations for the ~~six~~three months ended ~~June~~March 3031, ~~2004~~2005 are not necessarily indicative of the results to be expected for the full year.

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 ~~which will be~~ determined at year end by Petroleum Development Corporation's (the Managing General Partner's) petroleum ~~engineer~~engineers. If a determination is made that an exploratory well has not discovered economically producible reserves, then its costs are expensed as dry hole ~~costs~~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 ~~oil and~~ 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 ~~responsibilities~~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 ~~net~~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 ~~royalties~~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.

5The Managing General Partner currently uses the "Net-Back" method of accounting for transportation arrangements of natural gas sales. ~~Derivative~~ The ~~Instruments~~Managing General Partner sells gas at the wellhead and collects ~~Hedging~~a ~~Activities~~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.

~~The~~Sales ~~Managing~~of ~~General~~oil ~~Partner~~are ~~utilizes~~recognized ~~commodity~~when persuasive ~~based~~evidence ~~derivative~~of ~~instruments~~a sales arrangement exists, the oil is verified as produced ~~hedges~~and tois ~~manage~~delivered in a ~~portion~~stock tank, collection of ~~the~~revenue ~~Partnership's~~from ~~exposure~~the tosale is ~~price~~reasonably ~~volatility~~assured ~~stemming~~and ~~from~~the ~~natural~~sales ~~gas~~price ~~production~~is determinable. The ~~These~~Partnership ~~instruments~~is currently ~~consist~~able ofto ~~costless~~sell ~~collars~~all ~~and~~the ~~option~~oil ~~contracts~~that ~~traded~~it oncan ~~the~~produce ~~CIG~~under ~~(Colorado~~existing ~~Interstate~~sales contracts ~~Gas~~with ~~Index)~~petroleum refiners and marketers. The ~~costless~~Partnership ~~collars~~does ~~and~~not refine ~~option~~any ~~contracts~~of ~~hedge~~its ~~committed~~oil ~~and~~production. The ~~anticipated~~Partnership's ~~natural~~crude ~~gas~~oil ~~sales~~production ~~generally~~is sold ~~forecasted~~ to ~~occur~~purchasers ~~within~~at aor 24near ~~month~~the ~~period.~~Partnership's ~~The~~wells ~~Managing~~under ~~General~~short-term ~~Partner~~purchase contracts ~~does~~at ~~not~~prices ~~hold~~and orin ~~issue~~accordance ~~derivatives~~with ~~for~~arrangements ~~trading~~that orare ~~speculative~~customary ~~purposes~~in the oil industry.

6. Change in Accounting Principle

In June 2001, the Financial Accounting Standard Board issued SFAS No. 143, "Accounting for Asset Retirement Obligations" that requires entities to record the fair value of a liability for an asset retirement obligation in the period in which it is incurred and a corresponding increase in the carrying amount of the related long-lived asset. This statement is effective for fiscal years beginning after June 15, 2002. The Partnership adopted SFAS No. 143 on January 1, 2003 and recorded a net asset of $3,376 and a related liability of $3,768 (using a 6% discount rate) and a cumulative effect of change in accounting principle on prior years of $(392).

-5-

PDC 2002-A LIMITED PARTNERSHIP

(A West Virginia Limited Partnership)

Notes to Financial Statements

(Unaudited)

~~New~~ 5. ~~Accounting~~Derivative ~~Standards~~Financial Instruments

AThe ~~reporting~~Managing ~~issue~~General Partner ~~has~~utilizes ~~arisen~~commodity ~~regarding~~based ~~the~~derivative ~~application~~instruments ofas ~~certain~~hedges ~~provisions~~to ofmanage ~~SFAS~~a portion ~~No.~~of ~~141~~the ~~and~~Partnership's ~~SFAS~~exposure ~~No. 142~~ to ~~companies~~price involatility ~~the~~stemming ~~extractive~~from ~~industries, including oil and~~ natural gas ~~companies~~production. ~~The~~These ~~issue~~instruments isconsist ~~whether SFAS No. 142 requires registrants to classify the costs~~ of ~~mineral~~CIG ~~rights~~ (~~leases)~~Colorado ~~associated~~Interstate ~~with~~Gas Index) ~~extracting~~based ~~oil~~contracts ~~and~~for ~~gas~~Colorado ~~intangible assets in the balance sheets~~production, ~~apart from other capitalized oil~~ and ~~gas~~NYMEX ~~property~~traded ~~costs, and provide specific footnote disclosures. Historically, the Partnership has included the costs of mineral rights associated with extracting~~ oil futures and ~~gas~~option ascontracts afor ~~component~~Colorado of oil ~~and gas properties~~production. The Ifcostless itcollars isand option ~~ultimately~~contracts ~~determined~~hedge ~~that~~committed ~~SFAS No. 142 requires oil~~ and ~~gas~~anticipated ~~companies to classify costs of mineral rights associated with extracting~~ oil and natural gas assales generally aforecasted ~~separate intangible assets line item on the balance sheet, the Partnership would be required~~ to ~~reclassify~~occur ~~the~~within ~~historical cost of approximately $167,784 of mineral rights associated with developed oil and gas properties as of June 30, 2004 and December 31, 2003 out of oil and gas properties and into~~ a ~~separate~~24 ~~intangible~~month ~~mineral rights assets line item~~period. The Partnership's ~~total balance sheet, cash flows and results of operations would~~ does not behold ~~affected~~or ~~since~~issue ~~such~~derivatives ~~intangible assets would continue to be amortized and assessed~~ for ~~impairment. There~~trading isor aspeculative ~~proposed FASB staff position issued that clarifies that reclassification will not be necessary under the exception to SFAS No~~purposes. ~~142 but the comment period is still open. Final resolution is expected by the end of the Partnership's third quarter.~~

All derivatives are recognized on the Partnership 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 variability of cash flows to be received 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 linking all derivatives that are designated as cash-flow hedges to 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 ~~net~~ working capital at ~~June~~March 3031, ~~2004~~2005 of $~~266~~276,~~351~~408.

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

Results of Operations

Three months ended June 30, 2004 compared with June 30, 2003

Oil and gas sales for the three months ended June 30, 2004 were $372,657 compared to $596,001 for the three months ended June 30, 2003, a decrease of $223,344 or 37.5%. The volume of natural gas sold for the three months ended June 30, 2004, was 83,992 Mcf at an average sales price of $3.88 per Mcf compared to 170,670 Mcf at an average price of $3.19 per Mcf for the three months ended June 30, 2003. The volume of oil sold for the three months ended June 30, 2004 was 1,330 barrels at an average sales price of $35.31 compared to 1,740 barrels at an average price of $29.68 for the three months ended June 30, 2003. The Lifting cost for the three months ended June 30, 2004 was $.85 per Mcfe compared to $.61 per Mcfe for the three months ended June 30, 2003. The increase is partially attributed to the increase in severance and property taxes. The fixed costs of operations and well maintenance are allocated to lower production volumes therefore increasing the lifting cost per Mcfe. The Partnership experienced a net income of $157,528 and distributed $389,574 to the partners for the three months ending June 30, 2004.

-6-

PDC 2002-A LIMITED PARTNERSHIP

(A West Virginia Limited Partnership)

Notes to Financial Statements

(Unaudited)

~~Six~~Results of ~~Months ended June 30, 2004 compared with June 30, 2003~~Operations

OilThree and gas sales for the six months ended JuneMarch 3031, 20042005 were $844,287 compared towith $1,388,045March for the six months ended June 30, 2003, a decrease of $543,758 or 39.2%. The volume of natural gas sold for the six months ended June 30, 2004, was 176,955 Mcf at an average sales price of $4.29 per Mcf compared to 368,726 Mcf at an average price of $3.43 per Mcf for the six months ended June 30, 2003. The volume of oil sold for the six months ended June 30, 2004 was 2,537 barrels at an average sales price of $33.31 compared to 3,861 barrels at an average price of $32.03 for the six months ended June 30, 2003. The Lifting cost for the six months ended June 30, 2004 was $.90 per Mcfe compared to $.61 per Mcfe for the six months ended June 30, 2003. The increase is partially attributed to the increase in severance and property taxes. The fixed costs of operations and well maintenance are allocated to lower production volumes therefore increasing the lifting cost per Mcfe. The Partnership experienced a net income of $400,191 and distributed $809,743 to the partners for the six months ending June 30, 2004.

Oil and gas sales for the three months ended March 31, 2005 were $371,955 compared to $471,630 for the three months ended March 31, 2004, a decrease of $99,675 or 21.1%. The ~~Partnership's~~volume ~~revenue~~of ~~from~~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 ~~and~~sold ~~gas~~for ~~will~~the bethree ~~affected~~months byended ~~changes~~March in31, ~~prices~~2005 was 2,064 barrels at an average sales price of $45. As24 acompared ~~result~~to 1,207 barrels at an average price of ~~changes~~$31.11 infor ~~federal~~the ~~regulations~~three months ended March 31, ~~gas~~2004. The ~~prices~~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 ~~highly~~allocated ~~dependent~~to lower onproduction volumes, therefore increasing the ~~balance~~lifting ~~between~~cost ~~supply~~per Mcfe. Depreciation, depletion and ~~demand~~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's ~~gas~~experienced ~~sales~~a ~~prices~~net ~~are~~income ~~subject~~of $115,307 and distributed $218,160 to the ~~increase~~partners ~~and~~for ~~decrease~~the ~~based~~three onmonths ~~various~~ended ~~market~~March ~~sensitive~~31, ~~indices~~2005.

~~Critical~~The ~~Accounting~~Partnership's ~~Policies~~revenue from oil and gas will be affected 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~~Critical Accounting accounting policies are very important to the portrayal of Partnership's financial condition and results of operations and require management's most subjective or complex judgments. The policies are as follows:Policies

~~Revenue~~ Certain ~~Recognition~~accounting policies are very important to 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:

~~Impairment~~Revenue Recognition. Sales of ~~Long-Lived~~natural ~~Assets~~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.

~~Depreciation,~~The Managing ~~Depletion~~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 ~~Amortization~~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.

~~Exploration~~Sales of oil are recognized when persuasive evidence of a sales arrangement exists, the oil is verified as produced and ~~development~~is ~~costs~~delivered ~~are~~in ~~accounted~~a ~~for~~stock bytank, collection of revenue from the ~~successful~~sale ~~efforts~~is ~~method~~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.

~~Costs of proved properties including leasehold acquisition, exploration and development costs and equipment are depreciated or depleted by the unit~~-of7-~~production method based on estimated proved developed oil and gas reserves.~~

~~The~~PDC ~~judgments~~2002-A used in applying the above policies are based on management's evaluation of the relevant facts and circumstances as of the date of the financial statements. Actual results may differ from those estimates. See additional discussions in this Management's Discussion and Analysis.LIMITED PARTNERSHIP

~~Item~~(A ~~3. Quantitative~~West ~~and~~Virginia Limited ~~Qualitative Disclosure About Market Rate Risk~~Partnership)

~~Market-Sensitive~~Notes ~~Instruments~~to ~~and Risk Management~~Financial Statements

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

Impairment of Long-7Lived Assets The Partnership assesses impairment of capitalized costs of proved oil and gas 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.

~~PDC~~Oil ~~2002-A~~and ~~LIMITED~~Gas ~~PARTNERSHIP~~Properties

(AExploration ~~West~~and development ~~Virginia~~costs ~~Limited~~are ~~Partnership)~~accounted for by the successful efforts method.

~~Notes~~The Partnership assesses impairment of capitalized costs of proved oil and gas properties by comparing net capitalized costs to ~~Financial~~estimated undiscounted ~~Statements~~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 estimated 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.

~~(Unaudited)~~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 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.

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

~~Natural~~Costs ~~gas~~of ~~and~~proved ~~oil~~properties, ~~prices~~including ~~have~~leasehold acquisitions, ~~been~~exploration ~~unusually~~and ~~volatile~~development ~~for~~costs ~~the past few years,~~ and ~~the Partnership anticipates continued volatility in the future. Currently~~equipment, the NYMEX futures reflect a market expectation of gas prices at Henry Hub close to or above record prices per million Btu's (mmbtu). The CIG price index has historically ranged from 80% to 90% of the NYMEX price. These prices look strong for 2004 although natural gas storage levels are ~~near~~depreciated and ~~normal~~depleted ~~levels~~by ~~following a period when storage levels had been at a five-year low. The Partnership believes this situation creates~~ the ~~possibility~~ unit-of-production ~~both~~method ~~periods~~based ofon ~~low~~estimated ~~prices~~proved developed oil and ~~continued~~gas ~~high prices~~reserves.

~~Because~~Upon ofsale ~~the~~or ~~uncertainty~~retirement ~~surrounding natural gas prices the Managing General Partner used hedging agreements to manage some~~ of ~~the~~complete ~~impact~~fields of ~~fluctuations~~depreciable or indepletable prices for the Managing General Partner and its various limited partnership's share of production. Through October of 2005 the Partnership has in place a series of costless collars and option contracts. Under the collar arrangementsproperty, if the ~~applicable~~book ~~index~~value ~~rises above the ceiling price~~thereof, ~~the~~less ~~Partnership~~proceeds ~~pays~~or ~~the~~salvage ~~counterparty~~value, is ~~however~~credited ifor ~~the~~charged ~~index drops below the floor the counterparty pays the Partnership. For the period from April 2004 through October 2004, the Partnership has floors in place in a range from $3.20~~ to $4income.17 Upon on 10,469 Mmbtu of monthly production and ceilings in place at $4.70 on 5,234 Mmbtu of monthly production. For the period of November 2004 through March 2005, the Partnership has floors in place at $5.04 on 8,375 Mmbtu of monthly production and ceilings in place at $6.00 on 4,188 Mmbtu of monthly production. For the period April 2005 through October 2005, the Partnership has floors in place at $3.10 on 6,979 Mmbtu of monthly production and ceilings in place at $4.43 on 3,490 Mmbtu of monthly production. Open option contracts maturing in the next twelve months are for the sales of 52,344 Mmbtu of natural gas with an average ceiling price of $5.17 and for the sale of ~~104,688 Mmbtu of natural gas with an average floor price of $4.11 and~~ a ~~fair~~partial ~~value~~unit of ~~$(7~~property,~~133). The~~ ~~maximum term over which~~ the proceeds ~~Partnership~~are iscredited ~~hedging exposure~~ to ~~variability~~accumulated ofdepreciation ~~cash flows for commodity price risk is 16 months. As of June 30, 2004 the Partnership had total option contracts for the sale of 66,302 Mmbtu of natural gas with an average ceiling price of $5.01~~ and ~~for the sale of 132,605 Mmbtu of natural gas with an average floor price of $3~~depletion.~~90. The fair value of these floors and ceilings as of June 30, 2004 is $(29,875).~~

AsRecently Issued ofAccounting June 30, 2004, the Partnership had total open oil future contracts on 1,115 barrels of oil with a total contract amount of $35,257 and a fair value of $(6,133). All of the oil future contracts mature within the next twelve months. Pronouncements

~~Disclosure~~Asset Retirement ~~of Limitations~~Obligations

AsOn March 30, 2005, the ~~information~~FASB ~~above~~issued ~~incorporates~~FASB ~~only~~Interpretation ~~those~~No. ~~exposures~~47, "Accounting for Conditional Asset Retirement Obligations" (FIN No. 47). This interpretation clarifies that ~~exist~~the atterm ~~June~~"conditional ~~30,~~asset ~~2004,~~retirement itobligation" ~~does~~as ~~not~~used ~~consider~~in Statement ~~those~~No. ~~exposures~~143 orrefers ~~positions~~to a legal obligation to perform an asset retirement activity in which ~~could~~the ~~arise~~timing ~~after~~and/or method of settlement are conditional on a future event that ~~date~~may or may not be within the control of the entity incurring the obligation. The Asobligation 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 ~~result~~future event. Accordingly, an entity is required to recognize a liability for the ~~Partnership's~~fair ~~ultimate~~value ~~realized~~of ~~gain~~a conditional asset retirement obligation if the fair value of the liability can be reasonably estimated. Uncertainty about the timing and/or ~~loss~~method ~~with~~of ~~respect~~settlement toof ~~commodity~~a ~~price~~conditional ~~fluctuations~~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 ~~depend~~be oneffective for the ~~exposures~~Partnership ~~that~~at ~~arise~~the ~~during~~end of the ~~period~~fiscal year ended December 31, 2005. The Partnership has not determined the impact on the Partnership's ~~hedging~~financial ~~strategies~~position ator ~~the~~results ~~time~~of ~~and~~operations ~~commodity~~of ~~prices~~the atapplication ~~the~~of FIN ~~time~~No. 47.

~~Item 4. Controls and Procedures~~-8-

~~Under~~ PDC 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 13a2002-~~14(c))~~A 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 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.LIMITED PARTNERSHIP

~~-8-~~(A West Virginia Limited Partnership)

~~CONFORMED~~Notes ~~COPY~~to Financial Statements

~~PART II - OTHER INFORMATION~~(Unaudited)

~~Item~~Disclosure Regarding ~~1. Legal~~Forward ~~Proceedings~~Looking Statements

~~None~~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.

~~Item~~When used 6in 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. ~~Exhibits~~ Because these forward-looking statements involve risks and ~~Reports~~uncertainties, onactual ~~Form~~results 8could differ materially from those expressed or implied by these forward-Klooking 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.

~~(a)~~Item ~~Exhibits~~3. Quantitative and Qualitative Disclosure About Market Rate Risk

Exhibit Name	Exhibit Number
Rule 13a-14(a)/15d-14(a) Certifications by Chief Executive Officer	31.1
Rule 13a-14(a)/15d-14(a)Certification by Chief Financial Officer	31.2
Section 1350 Certifications by Chief Executive Officer	32.1
Section 1350 Certifications by Chief Financial Officer	32.2

Market-Sensitive Instruments and Risk Management

~~(b)~~The Partnership's Noprimary ~~reports~~market onrisk ~~Form~~exposure ~~8-K~~is ~~have~~commodity ~~been~~price ~~filed~~risk. This exposure ~~during~~is ~~the~~discussed ~~quarter~~in ~~ended~~detail below:

~~June~~Commodity ~~30,~~Price ~~2004.~~Risk

~~SIGNATURES~~The Managing General Partner utilizes commodity-based derivative instruments as 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.

~~Pursuant~~The tofollowing ~~the~~tables ~~requirements~~summarize of the ~~Securities~~open ~~Exchange~~futures ~~Act~~and options ofcontracts ~~1934~~for the ~~registrant~~Partnership ~~has~~as ~~duly~~of ~~caused~~March ~~this~~31, ~~report~~2005 toand beMarch ~~signed~~31, on200 ~~its behalf by the undersigned thereunto duly authorized~~4.

	PDC 2002-A Limited Partnership (Registrant) By its Managing General Partner Petroleum Development Corporation
	Type	Quantity	Weighted	Total	Fair
Date: August 10, 2004	/s/ Steven R. Williams Steven R. Williams President
		Gas-Mmbtu	Average	Contract	Market
Date: August 10, 2004	/s/ Darwin L. Stump Darwin L. Stump Chief Financial Officer
		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)

~~-9-~~The maximum term over which the Partnership is hedging exposure to the variability of cash flows for commodity price risk is 19 months.

Disclosure of Limitations

As the information above incorporates only those exposures that exist at March 31, 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 4. Controls and Procedures

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.

-10-

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: 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-

Filing Compare · Colorado 2002A Limited Partnership