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 30, 2003

[ ] 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 000-49674

I.R.S. Employer Identification Number 55-0779832

PDC 2001-B 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 2001-B LIMITED PARTNERSHIP

(A West Virginia Limited Partnership)

INDEX

PART I - FINANCIAL INFORMATION		Page No.
Item 1.	Financial Statements
	Balance Sheets - June 30, 2003 (unaudited) and December 31, 2002	1

	Statements of Operations - Three and Six Months Ended June 30, 2003 and 2002 (unaudited)	2

	Statement of Partners' Equity - Six Months Ended June 30, 2003 (unaudited)	3

	Statements of Cash Flows- Six Months Ended June 30, 2003 and 2002 (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	7

Item 4.	Controls and Procedures	8

PART II OTHER INFORMATION

Item 1.	Legal Proceedings	9

Item 6.	Exhibits and Reports on Form 8-K	9

PDC 2001-B LIMITED PARTNERSHIP

(A West Virginia Limited Partnership)

Balance Sheets

June 30, 2003 and December 31, 2002


Assets
	2003	2002
	(Unaudited)

Current assets:
Cash	$ 1,487	4,136
Accounts receivable - oil and gas revenues	528,440	444,049
Total current assets	529,927	448,185

Oil and gas properties, successful efforts method	13,795,467	13,787,953
Less accumulated depreciation, depletion
and amortization	2,726,193	2,081,912
	11,069,274	11,706,041

	$11,599,201	12,154,226

Current Liabilities and Partners' Equity

Current liabilities:
Accrued expenses	$ 6,880	12,706
Total current liabilities	6,880	12,706

Asset retirement obligation	8,084	-

Partners' Equity	11,584,237	12,141,520


	$11,599,201	12,154,226

See accompanying notes to financial statements.

-1-

PDC 2001-B LIMITED PARTNERSHIP

(A West Virginia Limited Partnership)

Statements of Operations

Three and Six Months ended June 30, 2003 and 2002

(Unaudited)

	Three Months ended June 30,		Six Months ended June 30,
	2003	2002	2003	2002
Revenues:
Sales of oil and gas	$590,555	746,280	1,425,601	1,241,579
Interest income	337	16	719	51
	590,892	746,296	1,426,320	1,241,630
Expenses:
Lifting cost	153,478	149,166	318,033	209,498
Direct administration cost	16	604	135	604
Income tax preparation	-	1,330	-	1,330
Independent engineering fee	-	(686)	-	(686)
Depreciation, depletion, and amortization	296,047	631,284	643,146	942,576
	449,541	781,698	961,314	1,153,322

Income (loss) before cumulative effect of accounting change	141,351	(35,402)	465,006	88,308

Cumulative effect of accounting change	-	-	(1,586 )	-

Net income (loss) after cumulative effect of accounting change	$141,351	(35,402 )	463,420	88,308

Net income (loss) per limited and additional general partner unit	$ 179	(45 )	585	111

See accompanying notes to financial statements.

-2-

PDC 2001-B LIMITED PARTNERSHIP

(A West Virginia Limited Partnership)

Statement of Partners' Equity

Six Months ended June 30, 2003

(Unaudited)

	Limited and Additional General Partners	Managing General Partner	Accumulated Other Comprehensive Income	Total

Balance, December 31, 2002	$9,706,046	2,426,514	8,960	12,141,520

Distributions to partners	(802,598)	(200,648)	-	(1,003,246)

Comprehensive income:
Net income	370,736	92,684	-	463,420
Change in fair value of outstanding hedging positions			(5,304)
Less reclassification adjustments for settled contracts included in net income			(12,153 )
Other comprehensive loss			(17,457)	(17,457 )
Comprehensive income				445,963

Balance, June 30, 2003	$9,274,184	2,318,550	(8,497 )	11,584,237

See accompanying notes to financial statements.

-3-

PDC 2001-B LIMITED PARTNERSHIP

(A West Virginia Limited Partnership)

Statements of Cash Flows

Six Months ended June 30, 2003 and 2002

(Unaudited)

	2003	2002
Cash flows from operating activities:
Net income	$463,420	88,308
Adjustments to reconcile net income to net cash
provided from operating activities:
Depreciation, depletion and amortization	643,146	942,576
Cumulative effect of accounting change	1,586	-
Accretion of asset retirement obligation	119	-
Changes in operating assets and liabilities:
Increase in accounts receivable - oil and gas revenues	(93,351)	(349,737)
Decrease in accounts payable	(14,323 )	(12,025)
Net cash provided from operating activities	1,000,597	669,122

Cash flows from financing activities:
Distributions to partners	(1,003,246 )	(682,344 )
Net cash used by financing activities	(1,003,246 )	(682,344)

Net decrease in cash	(2,649)	(13,222)
Cash at beginning of period	4,136	16,445
Cash at end of period	$ 1,487	3,223

See accompanying notes to financial statements.

-4-

PDC 2001-B LIMITED PARTNERSHIP

(A West Virginia Limited Partnership)

Notes to Financial Statements

(Unaudited)

1. Accounting Policies

Reference is hereby made to the Partnership's Annual Report on Form 10-K for 2002, 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 except as noted below.

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 months ended June 30, 2003 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 the Managing General Partner's petroleum engineer. If a determination is made that an exploratory well has not discovered economically producible reserves, then its costs are expensed as dry hole costs.

4. Revenue Recognition

Sales of oil and natural gas are recognized when sold.

5. Derivative Instruments and Hedging Activities

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 production. These instruments consist of costless collars and option contracts traded on the New York Mercantile Exchange. The costless collars and option contracts hedge committed and anticipated natural gas sales generally forecasted to occur within a 12 month period. The Managing General Partner does not hold or issue derivatives for trading or speculative purposes.

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 $6,379 and a related liability of $7,965 (using a 6% discount rate) and a cumulative effect on change in accounting principle on prior years of $1,586.

-5-

PDC 2001-B LIMITED PARTNERSHIP

(A West Virginia Limited Partnership)

Notes to Financial Statements

(Unaudited)

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

Liquidity and Capital Resources

The Partnership was funded on September 5, 2001 with initial Limited and Additional General Partner contributions of $12,678,577 and the Managing General Partner's cash contribution of $2,757,591 in accordance with the Agreement. After payment of syndication costs of $1,331,251 and a one-time management fee of $316,964 the Partnership had available cash of $13,787,953 for Partnership activities.

The Partnership began exploration and development activities subsequent to the funding of the Partnership and completed well drilling activities by June 30, 2002. Nineteen wells have been drilled of which eighteen have been completed as producing wells.

The Partnership had net working capital at June 30, 2003 of $523,047.

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, 2003 compared with June 30, 2002

Oil and gas sales for the three months ended June 30, 2003 were $590,555 compared to $746,280 for the three months ended June 30, 2002, a decrease of $155,725 or 20.9%. The volume of natural gas sold for the three months ended June 30, 2003, was 150,079 Mcf at an average sales price of $3.09 per Mcf compared to 242,820 Mcf at an average sales price of $2.24 per Mcf for the three months ended June 30, 2002. Oil sales were 4,371 barrels at an average sales price of $29.02 per barrel for the three months ended June 30, 2003 compared to 8,319 barrels at an average sales price of $24.11 per barrel for the three months ended June 30, 2002. The Lifting cost for the three months ended June 30, 2003 was $0.87 per Mcfe compared to $0.51 per Mcfe for the three months ended June 30, 2002. While the Partnership experienced a net income of $141,351, depreciation, depletion and amortization is a non-cash expense and therefore the Partnership distributed $541,424 to the partners during the three months ending June 30, 2003.

Six months ended June 30, 2003 compared with June 30, 2002

Oil and gas sales for the six months ended June 30, 2003 were $1,425,601 compared to $1,241,579 for the six months ended June 30, 2002, an increase of $184,022 or 14.8%. The volume of natural gas sold for the six months ended June 30, 2003, was 331,413 Mcf at an average sales price of $3.82 per Mcf compared to 312,698 Mcf at an average sales price of $2.29 per Mcf for the six months ended June 30, 2002. Oil sales were 8,600 barrels at an average sales price of $31.26 per barrel for the six months ended June 30, 2003 compared to 20,731barrels at an average sales price of $25.34 per barrel for the six months ended June 30, 2002. The Lifting cost for the six months ended June 30, 2003 was $0.83 per Mcfe compared to $0.48 per Mcfe for the six months ended June 30, 2002. While the Partnership experienced a net income of $463,420, depreciation, depletion and amortization is a non-cash expense and therefore the Partnership distributed $1,003,246 to the partners during the six months ending June 30, 2003.

The Partnership's revenues 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 gas sales prices are subject to increase and decrease based on various market sensitive indices.

-6-

PDC 2001-B LIMITED PARTNERSHIP

(A West Virginia Limited Partnership)

Notes to Financial Statements

(Unaudited)

Critical Accounting Policies

Certain 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:

Impairment of Long-Lived 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.

The judgment 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.

Item 3. Quantitative and Qualititive 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

Natural gas and oil prices have been unusually volatile for the past few years, and the Partnership anticipates continued volatility in the future. Currently, the NYMEX futures reflect a market expectation of gas prices at Henry Hub close to or above record prices per million Btu's (mmbtu). These prices look strong for the remainder of the year with natural gas storage levels at five-year low levels. The Partnership believes that volatility creates the possibility of both periods of low prices and continued high prices.

Natural gas prices in Colorado remained low for most of 2002. In the fourth quarter of 2002 and continuing in the first six months of 2003, Colorado prices began to increase, although they continue to trail prices in other areas. The Managing General Partner believes the low prices in the Rocky Mountain Region, including Colorado, result from increasing local supplies that exceed the local demand and pipeline capacity available to move gas from the region. On May 1st of 2003, the Kern River pipeline expansion was completed and placed into service. The Kern River Pipeline Company has announced that the additional facilities will add about 900 million cubic feet per day of capacity for deliveries to Arizona, Nevada and southern California. This represents almost 30% of the prior pipeline capacity from the region to the West Coast and other markets outside the region. The Managing General Partner believes that the completion and start-up of the pipeline eliminated or reduced the local supply surplus, leading to improved natural gas prices in the region.

-7-

PDC 2001-B LIMITED PARTNERSHIP

(A West Virginia Limited Partnership)

Notes to Financial Statements

(Unaudited)

Because of the uncertainty surrounding gas prices the Managing General Partner used hedging agreements to manage some of the impact of fluctuations in prices for the Managing General Partner and its various limited partnership's share of production. Through March of 2004 the Partnership has in place a series of costless collars and option contracts. Under the collar arrangements, if the applicable index rises above the ceiling price, the Partnership pays the counterparty, however if the index drops below the floor the counterparty pays the Partnership. For the period from July 2003 through October 2003, the Partnership has floors in place at $2.50 on 10,523 Mmbtu of monthly production and ceilings in place at $3.13 on 2,631 Mmbtu of monthly production. For the period November, 2003 through March, 2004, the Partnership has floors in place at $3.50 on 6,314 Mmbtu of monthly production and ceilings in place at $5.26 on 6,314 Mmbtu of monthly production. Oil prices have softened from earlier in the year. While oil prices are influenced by supply and demand, global geopolitics may be the single most important determinant. The Partnership also has in place at June 30, 2003, hedges on 703 barrels a month for its Wattenberg Field oil production for the period from July 2003 through December 2003 at a price of $30.00 per barrel. The fair value of these floors, ceilings and hedges as of June 30, 2003 is $(8,497).

As of June 30, 2003 the Partnership had option contracts for the sale of 42,092 Mmbtu of natural gas with an average ceiling price of $4.72 and for the sale of 73,601 Mmbtu of natural gas with an average floor price of $2.93. The Partnership also has hedging contracts for the sale of 4,216 barrels of oil at $30.00 per barrel.

Disclosure of Limitations

As the information above incorporates only those exposures that exist at June 30, 2003, 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 Partnership has evaluated the effectiveness of the design and operation of its disclosure controls and procedures (as defined in Exchange Act Rule 13a-14(c)) within 90 days of the filing date of this quarterly report, 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 controls or in other factors that could significantly affect these controls subsequent to the date of their evaluation.

-8-

CONFORMED COPY

PART II - OTHER INFORMATION

Item 1. Legal Proceedings

None.

Item 6. Exhibits and Reports on Form 8-K

(a) Exhibits

Exhibit Name	Exhibit Number

Rule 13a-14(a)/15d-14(a) Certifications by Chief Executive Officer	31
Rule 13a-14(a)/15d-14(a)Certifications by Chief Financial Officer	31
Section 1350 Certifications by Chief Executive Officer	32

Section 1350 Certifications by Chief Financial Officer	32

(b) No reports on Form 8-K have been filed during the quarter ended

June 30, 2003.

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 2001-B Limited Partnership (Registrant) By its Managing General Partner Petroleum Development Corporation



Date: August 7, 2003	/s/ Steven R. Williams Steven R. Williams President


Date: August 7, 2003	/s/ Dale G. Rettinger Dale G. Rettinger Executive Vice President and Treasurer

-9-

PDC 2001 B LP 10-Q