PDC 2002 B LTD PARTNERSHIP - FORM 10-Q - May 10, 2013

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EX-32.1 - 906 CERTIFICATION OF CHIEF EXECUTIVE OFFICER AND CHIEF FINANCIAL OFFICER - PDC 2002 B LTD PARTNERSHIPpdc2002b-ex321_20130331.htm
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EX-31.1 - 302 CERTIFICATION OF CHIEF EXECUTIVE OFFICER - PDC 2002 B LTD PARTNERSHIPpdc2002b-ex311_20130331.htm
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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, DC 20549

FORM 10-Q

S  QUARTERLY REPORT PURSUANT TO SECTION 13 or 15(d) OF THE SECURITIES EXCHANGE ACT
OF 1934

For the quarterly period ended March 31, 2013
or

£  TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT
OF 1934 FOR THE TRANSITION PERIOD ____________ TO ____________

Commission File Number 000-50227

PDC 2002-B Limited Partnership

(Exact name of registrant as specified in its charter)
 
West Virginia
 
38-3648762
 
 
(State or other jurisdiction of incorporation or organization)
 
(I.R.S. Employer Identification No.)
 

1775 Sherman Street, Suite 3000
Denver, Colorado 80203
(Address of principal executive offices) (Zip code)

Registrant's telephone number, including area code: (303) 860-5800

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 R No £

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).   Yes R No £

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See definitions of "large accelerated filer," "accelerated filer" and "smaller reporting company" in Rule 12b-2 of the Exchange Act.
 
Large accelerated filer  £
 
Accelerated filer  £
 
 
 
 
 
 
 
Non-accelerated filer £
 
Smaller reporting company R
 
 
(Do not check if a smaller reporting company)
 
 

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).  Yes £  No R

As of March 31, 2013 this Partnership had 559.02 units of limited partnership interest and no units of additional general partnership interest outstanding.


PDC 2002-B Limited Partnership


TABLE OF CONTENTS





SPECIAL NOTE REGARDING FORWARD-LOOKING STATEMENTS

This Quarterly Report on Form 10-Q contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 (“Securities Act”) and Section 21E of the Securities Exchange Act of 1934 ("Exchange Act") regarding this Partnership's business, financial condition and results of operations. PDC Energy, Inc. (“PDC”) is the Managing General Partner of this Partnership. All statements other than statements of historical facts included in and incorporated by reference into this report are “forward-looking statements” within the meaning of the safe harbor provisions of the United States ("U.S.") Private Securities Litigation Reform Act of 1995. Words such as expects, anticipates, intends, plans, believes, seeks, estimates and similar expressions or variations of such words are intended to identify forward-looking statements herein. These statements relate to, among other things: estimated natural gas, natural gas liquids ("NGLs") and crude oil reserves; additional development plans; future production, expenses, cash flows and liquidity; anticipated capital expenditures; availability of additional midstream facilities and services in the Wattenberg Field and timing of that availability; the adequacy of this Partnership's insurance; the effectiveness of the Managing General Partner's derivative program in providing a degree of price stability; closing of and expected proceeds from this Partnership's pending asset disposition; and the Managing General Partner's future strategies, plans and objectives.
The above statements are not the exclusive means of identifying forward-looking statements herein. Although forward-looking statements contained in this report reflect the Managing General Partner's good faith judgment, such statements can only be based on facts and factors currently known to the Managing General Partner. Consequently, forward-looking statements are inherently subject to risks and uncertainties, including known and unknown risks and uncertainties incidental to the development, production and marketing of natural gas, NGLs and crude oil, and actual outcomes may differ materially from the results and outcomes discussed in the forward-looking statements.
Important factors that could cause actual results to differ materially from the forward-looking statements include, but are not limited to:
•
changes in production volumes and worldwide demand, including economic conditions that might impact demand;
•
volatility of commodity prices for natural gas, NGLs and crude oil;
•
the impact of governmental policies and/or regulations, including changes in environmental and other laws, the interpretation and enforcement related to those laws and regulations, liabilities arising thereunder and the costs to comply with those laws and regulations;
•
potential declines in the values of this Partnership's natural gas and crude oil properties resulting in impairments;
•
changes in estimates of proved reserves;
•
inaccuracy of reserve estimates and expected production rates;
•
potential for production decline rates from this Partnership's wells to be greater than expected;
•
availability of future cash flows for investor distributions or funding of development activities;
•
timing and extent of this Partnership's success in further developing and producing this Partnership's reserves;
•
the Managing General Partner's ability to acquire supplies and services at reasonable prices;
•
timing and receipt of necessary regulatory permits;
•
risks incidental to the additional development and operation of natural gas and crude oil wells;
•
this Partnership's future cash flows, liquidity and financial condition;
•
competition in the oil and gas industry;
•
availability of sufficient pipeline, gathering and other transportation facilities and related infrastructure to process and transport this Partnership's production, particularly in the Wattenberg Field, and the impact of these facilities on the price this Partnership receives for its production;
•
success of the Managing General Partner in marketing this Partnership's natural gas, NGLs and crude oil;
•
effect of natural gas derivative activities;
•
impact of environmental events, governmental and other third-party responses to such events and the Managing General Partner's ability to insure adequately against such events;
•
cost of pending or future litigation;
•
potential obstacles to completing this Partnership's pending asset disposition or other transactions, in a timely manner or at all, and purchase price or other adjustments relating to those transactions that may be unfavorable to this Partnership;
•
the Managing General Partner's ability to retain or attract senior management and key technical employees; and
•
success of strategic plans, expectations and objectives for future operations of the Managing General Partner.


- 1-

Further, this Partnership urges the reader to carefully review and consider the cautionary statements and disclosures made in this Quarterly Report on Form 10-Q, this Partnership's Annual Report on Form 10-K for the year ended December 31, 2012(“2012 Form 10-K”) filed with the U.S. Securities and Exchange Commission (“SEC”) on March 15, 2013 and this Partnership's other filings with the SEC for further information on risks and uncertainties that could affect this Partnership's business, financial condition, results of operations and cash flows. Readers are cautioned not to place undue reliance on forward-looking statements, which speak only as of the date of this report. This Partnership undertakes no obligation to update any forward-looking statements in order to reflect any event or circumstance occurring after the date of this report or currently unknown facts or conditions or the occurrence of unanticipated events. All forward looking statements are qualified in their entirety by this cautionary statement.

- 2-

PART I – FINANCIAL INFORMATION

Item 1. Financial Statements

PDC 2002-B Limited Partnership
Condensed Balance Sheets
(unaudited)

 
March 31, 2013
 
December 31, 2012*
Assets
 
 
 

Current assets:
 
 
 

Cash and cash equivalents
$
10,106

 
$
10,137

Accounts receivable
49,477

 
21,527

Crude oil inventory
17,859

 
24,499

Due from Managing General Partner-derivatives
112,556

 
180,165

Total current assets
189,998

 
236,328

 
 
 
 
Natural gas and crude oil properties, successful efforts method, at cost
2,196,032

 
3,167,657

Less: Accumulated depreciation, depletion and amortization
(1,595,371
)
 
(2,270,162
)
Natural gas and crude oil properties, net
600,661

 
897,495

Assets held for sale
272,904

 
—

Other assets
51,010

 
49,653

 
 
 
 
Total Assets
$
1,114,573

 
$
1,183,476

 
 
 
 
Liabilities and Partners' Equity
 
 
 
Current liabilities:
 
 
 
Accounts payable and accrued expenses
$
2,930

 
$
2,522

Due to Managing General Partner-derivatives
60,403

 
81,917

Due to Managing General Partner-other, net
61,704

 
67,520

Total current liabilities
125,037

 
151,959

Asset retirement obligations
160,955

 
223,265

Liabilities held for sale
66,082

 
—

Total liabilities
352,074

 
375,224

 
 
 
 
Commitments and contingent liabilities


 


 
 
 
 
Partners' equity:
 
 
 
   Managing General Partner
224,231

 
232,462

   Limited Partners - 559.02 units issued and outstanding
538,268

 
575,790

Total Partners' equity
762,499

 
808,252

Total Liabilities and Partners' Equity
$
1,114,573

 
$
1,183,476

    *Derived from audited 2012 balance sheet






See accompanying notes to unaudited condensed financial statements.

- 3-

PDC 2002-B Limited Partnership
Condensed Statements of Operations
(unaudited)

 
Three months ended March 31,
 
2013
 
2012
Revenues:
 
 
 
Natural gas, NGLs and crude oil sales
$
56,243

 
$
75,644

Commodity price risk management gain (loss), net
(19,945
)
 
61,124

Total revenues
36,298

 
136,768

Operating costs and expenses:
 
 
 
Natural gas, NGLs and crude oil production costs
30,102

 
22,071

Direct costs - general and administrative
30,686

 
28,858

Depreciation, depletion and amortization
17,574

 
48,721

Accretion of asset retirement obligations
2,775

 
2,578

Total operating costs and expenses
81,137

 
102,228

 
 
 
 
Income (loss) from continuing operations
(44,839
)
 
34,540

 
 
 
 
Interest income
5

 
5

Income (loss) from discontinued operations
6,315

 
(76,507
)
 
 
 
 
Net loss
$
(38,519
)
 
$
(41,962
)
 
 
 
 
Net loss allocated to partners
$
(38,519
)
 
$
(41,962
)
Less: Managing General Partner interest in net loss
(7,704
)
 
(8,392
)
Net loss allocated to Investor Partners
$
(30,815
)
 
$
(33,570
)
 
 
 
 
Net loss per Investor Partner unit
$
(55
)
 
$
(60
)
 
 
 
 
Investor Partner units outstanding
559.02

 
559.02













See accompanying notes to unaudited condensed financial statements.

- 4-

PDC 2002-B Limited Partnership
Condensed Statements of Cash Flows
(unaudited)

 
Three months ended March 31,
 
2013
 
2012
Cash flows from operating activities:
 
 
 
Net loss
$
(38,519
)
 
$
(41,962
)
Adjustments to net loss to reconcile to net cash from operating activities:
 
 
 
Depreciation, depletion and amortization
23,930

 
59,008

Accretion of asset retirement obligations
3,772

 
3,516

Unrealized (gain) loss on derivative transactions
46,095

 
(26,736
)
Changes in assets and liabilities:
 
 
 
Accounts receivable
(27,950
)
 
11,668

Crude oil inventory
6,640

 
(6,800
)
Other assets
(1,357
)
 
(1,917
)
Accounts payable and accrued expenses
408

 
15,606

Due to Managing General Partner-other, net
(5,816
)
 
(2,359
)
Net cash from operating activities
7,203

 
10,024

Cash flows from investing activities:
 
 
 
Capital expenditures for natural gas and crude oil properties
—

 
(656
)
Net cash from investing activities
—

 
(656
)
Cash flows from financing activities:
 
 
 
Distributions to Partners
(7,234
)
 
(9,399
)
Net cash from financing activities
(7,234
)
 
(9,399
)
 
 
 
 
Net change in cash and cash equivalents
(31
)
 
(31
)
Cash and cash equivalents, beginning of period
10,137

 
10,261

Cash and cash equivalents, end of period
$
10,106

 
$
10,230

 
 
 
 









See accompanying notes to unaudited condensed financial statements.

- 5-
PDC 2002-B Limited Partnership
NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS
March 31, 2013
(unaudited)


Note 1 - General and Basis of Presentation

PDC 2002-B Limited Partnership (“Partnership” or the “Registrant”) was organized in 2002 as a limited partnership, in accordance with the laws of the State of West Virginia, for the purpose of engaging in the exploration and development of natural gas and crude oil properties. Business operations commenced upon closing of an offering for the sale of Partnership units. Upon funding, this Partnership entered into a Drilling and Operating Agreement (“D&O Agreement”) with the Managing General Partner which authorizes PDC Energy, Inc. (“PDC”) to conduct and manage this Partnership's business. In accordance with the terms of the Limited Partnership Agreement (the “Agreement”), the Managing General Partner is authorized to manage all activities of this Partnership and initiates and completes substantially all Partnership transactions.

As of March 31, 2013, there were 498 limited partners in this Partnership (the “Investor Partners”). PDC is the designated Managing General Partner of this Partnership and owns a 20% Managing General Partner ownership in this Partnership. According to the terms of the Agreement, revenues, costs and cash distributions of this Partnership are allocated 80% to the Investor Partners, which are shared pro rata based upon the number of units in this Partnership, and 20% to the Managing General Partner. The Managing General Partner may repurchase Investor Partner units under certain circumstances provided by the Agreement, upon request of an individual Investor Partner. Through March 31, 2013, the Managing General Partner had repurchased 41.1 units of Partnership interests from the Investor Partners at an average price of $3,598 per unit. As of March 31, 2013, the Managing General Partner owned 25.9% of this Partnership.

Beginning in November 2009, when the Investor Partners' average annual rate of return fell below 12.8%, this Partnership modified the standard ownership-based pro-rata allocation of Partnership cash available for distribution, pursuant to the Performance Standard Obligation outlined in Section 4.02 of the Agreement. Distributions paid to the Managing General Partner were reduced and distributions to the Investor Partners were increased by $668 and $929 for the three months ended March 31, 2013 and 2012, respectively, as a result of the Preferred Cash Distribution made under the terms in Section 4.02. The Managing General Partner's obligation under Section 4.02 expired in February 2013. For more information concerning the Performance Standard Obligation, see Note 8, Partners' Equity and Cash Distributions, to this Partnership's financial statements included in the 2012 Form 10-K.

In the Managing General Partner's opinion, the accompanying unaudited condensed financial statements contain all adjustments (consisting of only normal recurring adjustments) necessary for a fair presentation of this Partnership's results for interim periods in accordance with accounting principles generally accepted in the United States of America ("U.S. GAAP") and with the instructions to Form 10-Q and Article 8 of Regulation S-X of the SEC. Accordingly, pursuant to such rules and regulations, certain notes and other financial information included in the audited financial statements have been condensed or omitted. The information presented in this Quarterly Report on Form 10-Q should be read in conjunction with this Partnership's audited financial statements and notes thereto included in this Partnership's 2012 Form 10-K. This Partnership's accounting policies are described in the Notes to Financial Statements in this Partnership's 2012 Form 10-K and updated, as necessary, in this Quarterly Report on Form 10-Q. The results of operations and cash flows for the three months ended March 31, 2013 are not necessarily indicative of the results to be expected for the full year or any other future period.

Certain reclassifications have been made to prior period financial statements to conform to the current year presentation. The reclassifications are mainly attributable to reporting as discontinued operations the results of operations related to the planned sale of this Partnership's Piceance Basin assets. The reclassifications had no impact on previously reported cash flows, net income or Partners’ equity. See Note 8, Assets Held for Sale, Divestitures and Discontinued Operations, for additional information regarding the planned divestiture.



- 6-
PDC 2002-B Limited Partnership
NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS
March 31, 2013
(unaudited)

Note 2 - Summary of Significant Accounting Policies

Recently Adopted Accounting Standards

On January 1, 2013, this Partnership adopted changes issued by the Financial Accounting Standards Board regarding the disclosure of offsetting assets and liabilities. These changes require an entity to disclose both gross and net information about both instruments and transactions eligible for offset in the statement of financial position and instruments and transactions subject to an enforceable master netting arrangement or similar agreement. The enhanced disclosures enable users of an entity’s financial statements to understand and evaluate the effect or potential effect of master netting arrangements on an entity’s financial position, including the effect or potential effect of rights of setoff associated with certain financial instruments and derivative instruments. This Partnership's adoption of these changes had no impact on the unaudited condensed financial statements.

Note 3 - Transactions with Managing General Partner

The Managing General Partner transacts business on behalf of this Partnership under the authority of the D&O Agreement. Revenues and other cash inflows received by the Managing General Partner on behalf of this Partnership are distributed to the Partners net of corresponding operating costs and other cash outflows incurred on behalf of this Partnership. The fair value of this Partnership's portion of open derivative instruments is recorded on the condensed balance sheets under the captions “Due from Managing General Partner-derivatives” in the case of net unrealized gains and “Due to Managing General Partner-derivatives” in the case of net unrealized losses.

The following table presents transactions with the Managing General Partner reflected in the condensed balance sheet line item “Due to Managing General Partner-other, net” which remain undistributed or unsettled with this Partnership's investors as of the dates indicated:

    
 
March 31, 2013
 
December 31, 2012
Natural gas, NGLs and crude oil sales revenues
collected from this Partnership's third-party customers
$
17,019

 
$
20,841

Commodity price risk management, realized gain
17,239

 
14,367

Other (1)
(95,962
)
 
(102,728
)
Total Due to Managing General Partner-other, net
$
(61,704
)
 
$
(67,520
)

(1)
All other unsettled transactions, excluding derivative instruments, between this Partnership and the Managing General Partner. The majority of these are operating costs and general and administrative costs which have not been deducted from distributions.


- 7-
PDC 2002-B Limited Partnership
NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS
March 31, 2013
(unaudited)

The following table presents Partnership transactions, excluding derivative transactions which are more fully detailed in Note 5, Derivative Financial Instruments, with the Managing General Partner for the three months ended March 31, 2013 and 2012. “Well operations and maintenance” and “Gathering, compression and processing fees” are included in the “Natural gas, NGLs and crude oil production costs” line item on the condensed statements of operations for continuing operations and in Note 8, Assets Held for Sale, Divestitures and Discontinued Operations, for discontinued operations.    
 
 Three months ended March 31,
 
2013
 
2012
 Well operations and maintenance
$
47,522

 
$
103,679

 Gathering, compression and processing fees
3,484

 
4,627

 Direct costs - general and administrative
30,686

 
28,858

 Cash distributions (1) (2)
1,017

 
1,451


(1)
Cash distributions include $490 and $501 during the three months ended March 31, 2013 and 2012, respectively, related to equity cash distributions for Investor Partner units repurchased by PDC.
(2)
Cash distributions to the Managing General Partner were reduced by $668 and $929 during the three months ended March 31, 2013 and 2012, respectively, due to Preferred Cash Distributions made by the Managing General Partner to Investor Partners under the Performance Standard Obligation provision of the Agreement. For more information concerning this obligation, see Note 1, General and Basis of Presentation.


Note 4 - Fair Value of Financial Instruments

Determination of fair value. This Partnership's fair value measurements are estimated pursuant to a fair value hierarchy that requires this Partnership to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. The valuation hierarchy is based upon the transparency of inputs to the valuation of an asset or liability as of the measurement date, giving the highest priority to quoted prices in active markets (Level 1) and the lowest priority to unobservable data (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. In these cases, the lowest level input that is significant to a fair value measurement in its entirety determines the applicable level in the fair value hierarchy. Assessing the significance of a particular input to the fair value measurement in its entirety requires judgment, considering factors specific to the asset or liability, and may affect the valuation of the assets and liabilities and their placement within the fair value hierarchy levels. The three levels of inputs that may be used to measure fair value are defined as:

Level 1 - Quoted prices (unadjusted) for identical assets or liabilities in active markets.

Level 2 - Inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability and inputs that are derived from observable market data by correlation or other means.

Level 3 - Unobservable inputs for the asset or liability, including situations where there is little, if any, market activity.

The Managing General Partner measures the fair value of this Partnership's derivative instruments based on a pricing model that utilizes market-based inputs, including but not limited to the contractual price of the underlying position, current market prices, natural gas forward curve, discount rates such as the LIBOR curve for a similar duration of each outstanding position, volatility factors and nonperformance risk. Nonperformance risk considers the effect of the Managing General Partner's credit standing on the fair value of derivative liabilities and the effect of the Managing General Partner's counterparties' credit standings on the fair value of derivative assets. Both inputs to the model are based on published credit default swap rates and the duration of each outstanding derivative position.


- 8-
PDC 2002-B Limited Partnership
NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS
March 31, 2013
(unaudited)

The Managing General Partner validates its fair value measurement through the review of counterparty statements and other supporting documentation, the determination that the source of the inputs is valid, the corroboration of the original source of inputs through access to multiple quotes, if available, or other information and monitoring changes in valuation methods and assumptions. While the Managing General Partner uses common industry practices to develop its valuation techniques, changes in the Managing General Partner's pricing methodologies or the underlying assumptions could result in significantly different fair values. While the Managing General Partner believes its valuation method is appropriate and consistent with those used by other market participants, the use of a different methodology or assumptions to determine the fair value of certain financial instruments could result in a different estimate of fair value.

The Managing General Partner's derivative agreements contain master netting provisions that provide for the net settlement of all contracts through a single payment in the event of early termination. The Managing General Partner has elected not to offset the fair value positions recorded on the unaudited condensed balance sheets for this Partnership.
 
This Partnership's fixed-price swaps and basis swaps are included in Level 2. The following table presents this Partnership's derivative assets and liabilities measured at fair value on a recurring basis:
 
Balance Sheet
 
March 31, 2013
 
December 31, 2012
 
Line Item
 
 Level 2
 
 Level 2
 
 
 
 
 
 
Assets:
 
 
 
 
 
Current
 
 
 
 
 
Commodity-based derivatives
Due from Managing General Partner-derivatives
 
$
112,556

 
$
180,165

 Total assets
 
 
112,556

 
180,165

 
 
 
 
 
 
Liabilities:
 
 
 
 
 
Current
 
 
 
 
 
Basis protection derivative contracts
Due to Managing General Partner-derivatives
 
60,403

 
81,917

 Total liabilities
 
 
60,403

 
81,917

 Net asset
 
 
$
52,153

 
$
98,248


Non-Derivative Financial Assets and Liabilities

The carrying values of the financial instruments included in current assets and current liabilities approximate fair value due to the short-term maturities of these instruments.



- 9-
PDC 2002-B Limited Partnership
NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS
March 31, 2013
(unaudited)

Note 5 - Derivative Financial Instruments

As of March 31, 2013, this Partnership had derivative instruments in place for all of its anticipated 2013 natural gas production totaling 37,718 MMBtu. Partnership policy prohibits the use of natural gas and crude oil derivative instruments for speculative purposes.

The following tables present the impact of this Partnership's derivative instruments on this Partnership's accompanying condensed statements of operations:
 
 
 Three months ended March 31,
 
 
2013
 
2012
Statement of operations line item:
 
Reclassification of Realized Gains (Losses) Included in Prior Periods Unrealized
 
Realized and Unrealized Losses For the Current Period
 
Total
 
Reclassification of Realized Gains (Losses) Included in Prior Periods Unrealized
 
Realized and Unrealized Gains For the Current Period
 
Total
Commodity price risk management gain (loss), net
 
 
 
 
 
 
 
 
 
 
 
 
Realized gains (losses)
 
$
26,669

 
$
(519
)
 
$
26,150

 
$
30,872

 
$
3,516

 
$
34,388

Unrealized gains (losses)
 
(26,669
)
 
(19,426
)
 
(46,095
)
 
(30,872
)
 
57,608

 
26,736

Total
$
—

 
$
(19,945
)
 
$
(19,945
)
 
$
—

 
$
61,124

 
$
61,124


Derivative Counterparties. The Managing General Partner's derivative arrangements expose this Partnership to the credit risk of nonperformance by the counterparties. The Managing General Partner primarily uses financial institutions who are also lenders under the Managing General Partner's revolving credit facility as counterparties to its derivative contracts. To date, the Managing General Partner has had no counterparty default losses. The Managing General Partner has evaluated the credit risk of this Partnership's derivative assets from counterparties using relevant credit market default rates, giving consideration to amounts outstanding for each counterparty and the duration of each outstanding derivative position. Based on this evaluation, the Managing General Partner has determined that the potential impact of nonperformance of the Managing General Partner's counterparties on the fair value of this Partnership's derivative instruments was not significant.

Note 6 - Commitments and Contingencies

Legal Proceedings

Neither this Partnership nor PDC, in its capacity as the Managing General Partner of this Partnership, are party to any pending legal proceeding that PDC believes would have a materially adverse effect on this Partnership's business, financial condition, results of operations or liquidity.

Environmental

Due to the nature of the oil and gas industry, this Partnership is exposed to environmental risks. The Managing General Partner has various policies and procedures in place to prevent environmental contamination and mitigate the risks from environmental contamination. The Managing General Partner conducts periodic reviews to identify changes in this Partnership's environmental risk profile. Liabilities are accrued when environmental remediation efforts are probable and the costs can be reasonably estimated. These liabilities are reduced as remediation efforts are completed or are adjusted as a consequence of subsequent periodic reviews. Liabilities for environmental remediation efforts are included in line item captioned “Accounts payable and accrued expenses” on the condensed balance sheet.

During the three months ended March 31, 2013, as a result of the Managing General Partner's periodic review, no new environmental remediation liabilities were identified and this Partnership's expense for environmental remediation efforts was not significant. This Partnership recorded no environmental remediation liabilities as of March 31, 2013. Environmental remediation liabilities as of December 31, 2012 were not significant.


- 10-
PDC 2002-B Limited Partnership
NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS
March 31, 2013
(unaudited)

The Managing General Partner is not currently aware of any environmental claims existing as of March 31, 2013 which have not been provided for or would otherwise have a material impact on this Partnership's condensed financial statements; however, there can be no assurance that current regulatory requirements will not change or unknown past non-compliance with environmental laws will not be discovered on this Partnership's properties.




Note 7 - Asset Retirement Obligations

The following table presents the changes in carrying amounts of the asset retirement obligations associated with this Partnership's working interest in natural gas and crude oil properties:

 
Three months ended
 
March 31, 2013
 
 
Beginning balance
$
223,265

Accretion expense
3,772

Ending balance
227,037

Liabilities held for sale (1)
(66,082
)
Long-term portion
$
160,955


(1)
Represents asset retirement obligations related to this Partnership's assets held for sale. See Note 8, Assets Held for Sale, Divestitures and Discontinued Operations, for additional information regarding the planned sale of these properties.
 
Note 8 - Assets Held for Sale, Divestitures and Discontinued Operations

Piceance Basin. On February 4, 2013, this Partnership's Managing General Partner entered into a purchase and sale agreement ("PSA") with certain affiliates of Caerus Oil and Gas LLC (“Caerus”), pursuant to which this Partnership agreed to sell to Caerus all of its Piceance Basin assets for cash consideration of approximately $431,000, subject to post-closing adjustments. Under the same PSA, PDC has agreed to sell to Caerus PDC's and PDC sponsored partnerships' Piceance Basin assets and certain non-core Colorado oil and gas properties, leasehold mineral interests and related assets. Based on the amounts allocated to this Partnership in the PSA, PDC determined that it was in the best interest of this Partnership to sell its Piceance Basis assets under the PSA. The PSA does not include any of this Partnership's Wattenberg Field assets. These assets have been classified as held for sale in the unaudited condensed balance sheet as of March 31, 2013. The cash consideration is subject to customary adjustments, including adjustments based upon title and environmental due diligence and with respect to natural gas derivative position settlements that will be assumed by Caerus. The Managing General Partner intends to use the proceeds from the asset disposal for operational needs, for additional reserve development of natural gas, NGLs and crude oil production in the Wattenberg Field (the "Additional Development Plan") or distributions to Partners. There can be no assurance this Partnership will be successful in closing such divestiture. Following the planned sale, this Partnership will not have significant continuing involvement in the operations of, or cash flows from, the Piceance Basin oil and gas properties. Accordingly, the results of operations related to these assets have been separately reported as discontinued operations in the unaudited condensed statement of operations for all periods presented.
Selected financial information related to divested and discontinued operations. The tables below set forth selected financial information related to this Partnership's Piceance Basin net assets held for sale and operating results related to discontinued operations. Net assets held for sale represents this Partnership's Piceance Basin assets that are expected to be sold, net of liabilities that are expected to be assumed by Caerus. While the reclassification of revenues and expenses related to discontinued operations for the 2012 period had no impact upon previously reported net earnings, the statement of operations table presents the revenues and expenses that were reclassified from the specified statement of operations line items to discontinued operations.


- 11-
PDC 2002-B Limited Partnership
NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS
March 31, 2013
(unaudited)

The following table presents balance sheet data related to assets held for sale:
 
As of
 
March 31, 2013
 
 
 
 Net Assets
Balance Sheet
 Held for Sale
 
 
Assets
 
Properties, successful efforts method, at cost
$
971,625

Accumulated depreciation, depletion and amortization
(698,721
)
Total assets
272,904

 
 
Liabilities
 
Asset retirement obligations
66,082

 
 
Net Assets
$
206,822



The following table presents statements of operations data related to this Partnership's discontinued operations:

 
 
 Three Months Ended March 31,
Statement of Operations - Discontinued Operations
 
2013
 
2012
 
 
 
 
 
Revenues:
 
 
 
 
Natural gas, NGLs and crude oil sales
 
$
38,800

 
$
25,524

Total revenues
 
38,800

 
25,524

 
 
 
 
 
Operating costs and expenses:
 
 
 
 
Natural gas, NGLs and crude oil production costs
 
25,132

 
90,806

Depreciation, depletion and amortization
 
6,356

 
10,287

Accretion of asset retirement obligations
 
997

 
938

Total operating costs and expenses
 
32,485

 
102,031

 
 
 
 
 
Income (loss) from discontinued operations
 
$
6,315

 
$
(76,507
)


- 12-
PDC 2002-B Limited Partnership
(A West Virginia Limited Partnership)



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

Partnership Overview

PDC 2002-B Limited Partnership engages in the development, production and sale of natural gas, NGLs and crude oil. This Partnership began natural gas and crude oil operations in September 2002 and operates 14 gross (12.8 net) productive wells located in the Rocky Mountain Region of Colorado. The Managing General Partner markets this Partnership's natural gas and crude oil production to midstream marketers. Natural gas, NGLs and crude oil is sold primarily under market-sensitive contracts in which the price varies as a result of market forces. PDC does not charge a separate fee for the marketing of the natural gas, NGLs and crude oil because these services are covered by the monthly well operating charge. PDC, on behalf of this Partnership in accordance with the D&O Agreement, is authorized to enter into multi-year fixed price contracts and/or to utilize derivatives, including collars, swaps or basis protection swaps, in order to offset some or all of the commodity price variability for particular periods of time. Seasonal factors, such as effects of weather on prices received, costs incurred and availability of PDC or third-party owned pipeline capacity, and other factors such as high pressures in the gathering system whether caused by heat or third-party facilities issues, may impact this Partnership's results. In addition, both sales volumes and prices tend to be affected by demand factors with a seasonal component.

Due to the Investor Partners' average annual rate of return being less than 12.8% in November 2009, this Partnership modified the standard ownership-based pro-rata allocation of Partnership cash available for distribution. This modified distribution ended in 2013. See Note 1, General and Basis of Presentation, to the unaudited condensed financial statements included in this report and "Financial Condition, Liquidity and Capital Resources - Cash Flows" below for additional information and the effect of this modification on distributions.

Recent Developments

Planned Natural Gas and Crude Oil Properties Divestitures

On February 4, 2013, this Partnership's Managing General Partner entered into a PSA with certain affiliates of Caerus, pursuant to which this Partnership agreed to sell to Caerus all of its Piceance Basin oil and gas properties for cash consideration of approximately $431,000. The cash consideration is subject to customary adjustments, including adjustments based upon title and environmental due diligence and with respect to natural gas derivative positions that will be assumed by Caerus. Under the same PSA, PDC has agreed to sell to Caerus PDC's and PDC sponsored partnerships' Piceance Basin assets and certain non-core Colorado oil and gas properties, leasehold mineral interests and related assets. Based on the amounts allocated to this Partnership in the PSA, PDC determined that it was in the best interest of this Partnership to sell its Piceance Basis assets under the PSA. The PSA does not include any of this Partnership's Wattenberg Field assets. The effective date of the transaction is January 1, 2013. The Managing General Partner intends to use the proceeds from the sale for this Partnership's operational needs, for the Additional Development Plan or distributions to Partners. As of December 31, 2012, total estimated proved reserves related to these assets were 144 MMcf of natural gas and 1 MBbl of crude oil, for an aggregate of 25 MBbl of crude oil equivalent. See Note 8, Assets Held for Sale, Divestitures and Discontinued Operations, to this Partnership's unaudited condensed financial statements included elsewhere in this report for additional details related to the planned divestiture of this Partnership's Piceance assets. There can be no assurance that this transaction will close as planned. In addition, purchase price adjustments may reduce this Partnership's proceeds from the transaction.

Partnership Operating Results Overview

Natural gas, NGLs and crude oil sales from continuing operations decreased 26%, or approximately $19,000, for the first three months of 2013 compared to the first three months of 2012, while sales volumes from continuing operations decreased 32% period-to-period. Partially offsetting this decrease, the average sales price per barrel of crude oil equivalent ("Boe"), excluding the impact of realized derivative gains, was $52.22 for the current period compared to $47.91 for the same period a year ago. Realized gains from all natural gas derivatives contributed approximately $26,000 to total revenues for the first three months of 2013 compared to approximately $34,000 from natural gas derivatives for the first three months of 2012.

- 13-
PDC 2002-B Limited Partnership
(A West Virginia Limited Partnership)




Results of Operations

Summary Operating Results

The following table presents selected information regarding this Partnership’s results from continuing operations:
 
 Three months ended March 31,
 
2013
 
2012
 
 Change
Number of gross producing wells (end of period)
11

 
11

 
—

 
 
 
 
 
 
Production(1)
 
 
 
 
 
Natural gas (Mcf)
2,540

 
4,480

 
(43
)%
NGLs (Bbl)
173

 
265

 
(35
)%
Crude oil (Bbl)
481

 
567

 
(15
)%
Crude oil equivalent (Boe)(2)
1,077

 
1,579

 
(32
)%
Average Boe per day
12

 
17

 
(32
)%
 
 
 
 
 
 
Natural gas, NGLs and crude oil sales
 
 
 
 
 
Natural gas
$
7,516

 
$
11,801

 
(36
)%
NGLs
7,279

 
10,119

 
(28
)%
Crude oil
41,448

 
53,724

 
(23
)%
Total natural gas, NGLs and crude oil sales
$
56,243

 
$
75,644

 
(26
)%
 
 
 
 
 
 
Realized gain on derivatives, net
 
 
 
 
 
Natural gas
$
26,150

 
$
34,388

 
(24
)%
Total realized gain on derivatives, net
$
26,150

 
$
34,388

 
(24
)%
 
 
 
 
 
 
Average selling price (excluding realized gain on derivatives)
 
 
 
 
 
Natural gas (Mcf)
$
2.96

 
$
2.63

 
12
 %
NGLs (Bbl)
42.08

 
38.18

 
10
 %
Crude oil (per Bbl)
86.17

 
94.75

 
(9
)%
Crude oil equivalent (per Boe)
52.22

 
47.91

 
9
 %
 
 
 
 
 
 
Average cost per Boe
 
 
 
 
 
Natural gas, NGLs and crude oil production cost(3)
$
27.95

 
$
13.98

 
100
 %
Depreciation, depletion and amortization
16.32

 
30.86

 
(47
)%
 
 
 
 
 
 
Operating costs and expenses
 
 
 
 
 
Direct costs - general and administrative
$
30,686

 
$
28,858

 
6
 %
Depreciation, depletion and amortization
17,574

 
48,721

 
(64
)%
 
 
 
 
 
 
Cash distributions
$
7,234

 
$
9,399

 
(23
)%
Amounts may not recalculate due to rounding.
   

_______________
(1) Production is net and determined by multiplying the gross production volume of properties in which this Partnership has an interest by the average percentage of the leasehold or other property interest this Partnership owns.
(2) One Bbl of crude oil or NGL equals six Mcf of natural gas.
(3) Represents natural gas, NGLs and crude oil operating expenses, including production taxes.


- 14-
PDC 2002-B Limited Partnership
(A West Virginia Limited Partnership)


Definitions used throughout Management’s Discussion and Analysis of Financial Condition and Results of Operations:

Bbl - One barrel of crude oil or natural gas liquids ("NGLs") or 42 gallons of liquid volume.
Boe - Barrels of crude oil equivalent.
MBbl - One thousand barrels of crude oil or NGLs.
Mcf - One thousand cubic feet of natural gas volume.
Mcfe - One thousand cubic feet of natural gas equivalent (six Mcf of natural gas equals one Bbl of crude oil or NGL).
MMBtu - One million British thermal units.
MMcf - One million cubic feet of natural gas volume.
MMcfe - One million cubic feet of natural gas equivalent.


Natural Gas, NGLs and Crude Oil Sales

Natural Gas, NGLs and Crude Oil Pricing. This Partnership's results of operations depend upon many factors, particularly the price of natural gas, NGLs and crude oil and the Managing General Partner's ability to market this Partnership's production effectively. Natural gas, NGLs and crude oil prices are among the most volatile of all commodity prices. These price variations can have a material impact on this Partnership's financial results and capital expenditures.

Natural gas prices vary by region and locality, depending upon the distance to markets, availability of pipeline capacity and supply and demand relationships in that region or locality. The price this Partnership receives for its natural gas produced is based on the Colorado Interstate Gas ("CIG") price. This Partnership's NGL price is mainly based on prices from the Conway hub in Kansas where the Wattenberg production is marketed. Crude oil pricing is predominately driven by the physical market, supply and demand, the financial markets and national and international politics. The majority of this Partnership's crude oil is sold on a calendar-year basis at a fixed differential to NYMEX pricing.

This Partnership currently uses the "net-back" method of accounting for these arrangements related to its natural gas sales. This Partnership sells natural gas at the wellhead and collects a price and recognizes revenues based on the wellhead sales price as transportation costs downstream of the wellhead are incurred by the purchaser and reflected in the wellhead price. The net-back method results in the recognition of a sales price that is below the indices for which the production is based.

Recently, a combination of increased drilling activity and curtailments due to limited capacity on local gathering and processing infrastructure and, in some periods, higher temperatures, has resulted in capacity constraints in the Wattenberg Field. The Managing General Partner anticipates that this Partnership will again experience high line pressures in 2013, particularly in the summer months, as field-wide production volumes from the ongoing development of the successful horizontal Wattenberg play outpace current midstream capacity. The Managing General Partner is working closely with the primary midstream provider in the Wattenberg Field who is implementing a multi-year facility expansion capable of significantly increasing long-term gathering and processing capacity. The Managing General Partner expects reduced line pressures to substantially benefit this Partnership in late 2013, concurrent with the startup of the LaSalle gas plant and associated field compressor stations. Like most producers, this Partnership relies on its third-party midstream service providers to construct compression, gathering and processing facilities to keep pace with production growth. As a result, the timing and availability of these facilities is beyond this Partnership's or the Managing General Partner's control.


- 15-
PDC 2002-B Limited Partnership
(A West Virginia Limited Partnership)


Three months ended March 31, 2013 as compared to three months ended March 31, 2012

For the three months ended March 31, 2013 compared to the same period in 2012, natural gas, NGLs and crude oil production from continuing operations, on an energy equivalency-basis, decreased 32% primarily due to normal production declines for this stage in the wells’ production life cycle and a decrease in production precipitated by curtailments due to high line pressure in the Wattenberg Field.

The approximately $19,000, or 26%, decrease in sales from continuing operations for the 2013 three month period as compared to the prior year period was a reflection of sales volume decreases of 32% partially offset by an increase in the average sales price of 9%. The average sales price per Boe, excluding the impact of realized derivative gains, was $52.22 for the current year three month period compared to $47.91 for the same period a year ago.

Natural gas, NGLs and crude oil sales from continuing operations for the three months ended March 31, 2013 decreased by 36%, 28% and 23%, respectively, as compared to the three months ended March 31, 2012. The decrease in natural gas sales resulted from lower natural gas production volumes of 43%, partially offset by increased prices per Mcf of 12%. The decrease in NGLs sales was due to a decrease of 35% in production volumes, partially offset by an increase in the average commodity price per Bbl of 10%. The crude oil sales decrease was due to a production volume decrease of 15% and a decrease in the average commodity price per Bbl of 9%.

Commodity Price Risk Management

This Partnership uses various derivative instruments to manage fluctuations in natural gas prices. This Partnership has in place collars, fixed-price swaps and/or basis swaps on a portion of this Partnership's estimated natural gas production. This Partnership sells its natural gas at similar prices to the indices inherent in this Partnership's derivative instruments. As a result, for the volumes underlying this Partnership's derivative positions, this Partnership ultimately realizes a price related to its collars of no less than the floor and no more than the ceiling and, for this Partnership's commodity swaps, this Partnership ultimately realizes the fixed price related to its swaps.

Commodity price risk management includes realized gains and losses and unrealized mark-to-market changes in the fair value of the derivative instruments related to this Partnership's natural gas production. See Note 4, Fair Value of Financial Instruments, and Note 5, Derivative Financial Instruments, to this Partnership's unaudited condensed financial statements included elsewhere in this report for additional details of this Partnership's derivative financial instruments.

The following table presents the realized and unrealized derivative gains and losses included in commodity price risk management gain (loss), net:
 
Three months ended March 31,
 
2013
 
2012
Commodity price risk management gain (loss), net:
 
 
 
  Realized gains
 
 
 
  Natural gas
$
26,150

 
$
34,388

       Total realized gains, net
26,150

 
34,388

  Unrealized gains (losses)
 
 
 
Reclassification of realized gains included in
 
 
 
   prior periods unrealized gains
(26,669
)
 
(30,872
)
Unrealized gains (losses) for the period
(19,426
)
 
57,608

Total unrealized gains (losses), net
(46,095
)
 
26,736

Total commodity price risk management gain (loss), net
$
(19,945
)
 
$
61,124




- 16-
PDC 2002-B Limited Partnership
(A West Virginia Limited Partnership)


Three months ended March 31, 2013 as compared to three months ended March 31, 2012

Realized gains of approximately $26,000 recognized in the three months ended March 31, 2013 were primarily the result of lower natural gas spot prices at settlement compared to the respective strike price of this Partnership's natural gas derivative positions. For the three months ended March 31, 2013, realized gains on natural gas, exclusive of basis swaps, were approximately $49,000. These gains were offset in part by realized losses of approximately $23,000 on this Partnership's basis swap positions as the negative basis differential between NYMEX and CIG weighted-average price was narrower than the strike price of this Partnership's basis swaps.

Unrealized losses of approximately $19,000 for the quarter ended March 31, 2013 were primarily related to the upward shift in the natural gas forward curve and its impact on the fair value of this Partnership's open positions.

Realized gains of approximately $34,000 recognized in the three months ended March 31, 2012 were primarily the result of lower natural gas spot prices at settlement compared to the respective strike price of this Partnership's natural gas derivative positions. For the three months ended March 31, 2012, realized gains on natural gas, exclusive of basis swaps, were approximately $59,000. These gains were offset in part by realized losses of approximately $25,000 on this Partnership's basis swap positions as the negative basis differential between NYMEX and CIG weighted-average price was narrower than the strike price of this Partnership's basis swaps.

Unrealized gains of approximately $58,000 for the three months ended March 31, 2012 were primarily related to the downward shift in the natural gas forward curve and its impact on the fair value of this Partnership's open positions.

The following table presents this Partnership's derivative positions in effect as of March 31, 2013:
 
 
Fixed-Price Swaps
 
CIG Basis Protection Swaps
 
 
 
Commodity/
Index
Quantity
(Gas-MMBtu(1))
 
Weighted-
Average
Contract
Price
 
Quantity
(Gas-MMBtu(1))
 
Weighted-
Average
Contract
Price
 

Fair Value at
March 31, 2013
 
 
 
 
 
 
 
 
 
 
 
 
 
Natural Gas
 
 
 
 
 
 
 
 
 
 
NYMEX
 
 
 
 
 
 
 
 
 
 
04/01 - 06/30/2013
12,786

 
$
7.12

 
12,786

 
$
(1.88
)
 
$
19,153

 
07/01 - 09/30/2013
12,614

 
7.12

 
12,614

 
(1.88
)
 
17,485

 
10/01 - 12/31/2013
12,318

 
7.12

 
12,318

 
(1.88
)
 
15,515

 
Total(2)
37,718

 
 
 
37,718

 
 
 
$
52,153


(1) A standard unit of measure for natural gas (one MMBtu equals one Mcf).
(2) Pursuant to a purchase and sale agreement entered into on February 4, 2013, approximately 26,952 MMBtu of the above Fixed-Price Swaps, and an equal amount of CIG Basis Protection Swaps, is expected to be assigned to certain affiliates of Caerus upon the closing of the planned sale. There can be no assurance that this transaction will close as planned. See Note 8, Assets held for Sale, Divestiture and Discontinued Operations, to this Partnership's financial statements included elsewhere in this report for additional information regarding the planned divestiture of certain of this Partnership's natural gas properties.



- 17-
PDC 2002-B Limited Partnership
(A West Virginia Limited Partnership)


Natural Gas, NGLs and Crude Oil Production Costs

Generally, natural gas, NGLs and crude oil production costs vary with changes in total natural gas, NGLs and crude oil sales and production volumes. Production taxes are estimates by the Managing General Partner based on tax rates determined using published information. These estimates are subject to revision based on actual amounts determined during future filings by the Managing General Partner with the taxing authorities. Production taxes vary directly with total natural gas, NGLs and crude oil sales. Transportation costs vary directly with production volumes. Fixed monthly well operating costs increase on a per unit basis as production decreases per the historical decline curve. In addition, general oil field services and all other costs vary and can fluctuate based on services required, but are expected to increase as wells age and require more extensive repair and maintenance.
These costs include water hauling and disposal, equipment repairs and maintenance, snow removal, environmental compliance and remediation and service rig workovers.

Three months ended March 31, 2013 as compared to three months ended March 31, 2012

Natural gas, NGLs and crude oil production costs for the three months ended March 31, 2013 increased approximately $8,000 compared to the same period in 2012 due primarily to higher lease operating costs in 2013 as workover activities were collectively lower in 2012. Natural gas, NGLs and crude oil production costs per Boe increased to $27.95 during 2013 from $13.98 in 2012 due to lower volumes.

Depreciation, Depletion and Amortization

Three months ended March 31, 2013 as compared to three months ended March 31, 2012

Depreciation, depletion and amortization ("DD&A") expense related to natural gas and crude oil properties is directly related to proved reserves and production volumes. DD&A expense for continuing operations decreased approximately $31,000 for the three months ended March 31, 2013 compared to the three months ended March 31, 2012 due to lower production volumes and by a decreased DD&A expense rate in 2013. The DD&A expense rate per Boe decreased to $16.32 for the 2013 three months compared to $30.86 during the same period in 2012 due to the effect of an impairment recorded for the Wattenberg Field assets as of December 31, 2012.

Discontinued Operations

On February 4, 2013, the Managing General Partner entered into a purchase and sale agreement with Caerus, pursuant to which this Partnership agreed to sell to Caerus its Piceance Basin assets for cash consideration of approximately $431,000, subject to post-closing adjustments. Following the planned sale, this Partnership will not have significant continuing involvement in the operations of, or cash flows from, the Piceance Basin assets. Accordingly, the results of operations related to these assets have been separately reported as discontinued operations in the unaudited condensed statement of operations for all periods presented.

See Note 8, Assets Held for Sale, Divestitures and Discontinued Operations, to the accompanying unaudited condensed financial statements included elsewhere in this report for additional information regarding the planned sale of this Partnership's Piceance Basin assets.

The table below presents production data related to this Partnership's Piceance Basin assets that are planned to be divested and that are classified as discontinued operations:

 
Three Months Ended March 31,
Discontinued Operations
2013
 
2012
Production
 
 
 
Natural gas (Mcf)
13,902

 
15,088

Crude oil (Bbl)
10

 
9

Crude oil equivalent (Boe)
2,327

 
2,524




- 18-
PDC 2002-B Limited Partnership
(A West Virginia Limited Partnership)


Financial Condition, Liquidity and Capital Resources

This Partnership's primary sources of cash for the three month periods ended March 31, 2013 and 2012 were operating activities, which include the sale of natural gas, NGLs and crude oil production, and to the net realized gains from this Partnership's derivative positions. These sources of cash were primarily used to fund this Partnership's operating costs, direct costs-general and administrative and monthly distributions to the Investor Partners and the Managing General Partner.

Fluctuations in this Partnership's operating cash flows are substantially driven by changes in commodity prices, sales volumes, which can be impacted by high line pressures, and realized gains and losses from commodity contracts. Commodity prices have historically been volatile and the Managing General Partner attempts to manage this volatility through the use of derivatives. Therefore, the primary source of cash flows from operations becomes the net activity between natural gas, NGLs and crude oil sales and realized natural gas derivative gains and losses. This Partnership does not engage in speculative positions, nor does this Partnership hold derivative instruments for 100% of this Partnership's expected future production from producing wells, and therefore may still experience significant fluctuations in cash flows from operations. As of March 31, 2013, this Partnership had natural gas derivative positions in place covering all of its expected natural gas production for the remainder of 2013 at an average price of $5.24 per Mcf. This Partnership has no NGLs or crude oil derivatives. See Results of Operations for further discussion of the impact of prices and volumes on sales from operations and the impact of derivative activities on this Partnership's revenues.

This Partnership's future operations are expected to be conducted with available funds and revenues generated from natural gas, NGLs and crude oil production activities and commodity derivatives. Natural gas, NGLs and crude oil production from existing properties are generally expected to continue a gradual decline in the rate of production over the remaining life of the wells. Therefore, this Partnership anticipates a lower annual level of natural gas, NGLs and crude oil production and, in the absence of significant price increases or additional reserve development, lower revenues. This Partnership also expects cash flows from operations to decline if commodity prices remain at current levels or decrease in the future. Under these circumstances, decreased production would have a material adverse impact on this Partnership's operations and may result in reduced cash distributions to the Managing General Partner and Investor Partners through the remainder of 2013 and beyond, and may substantially reduce or restrict this Partnership's ability to participate in Additional Development Plan activities.

Working Capital

At March 31, 2013, this Partnership had a working capital surplus of approximately $65,000, compared to a working capital surplus of approximately $84,000 at December 31, 2012. The decrease of approximately $19,000 was primarily due to the following changes:

•
accounts receivable increased by approximately $24,000 between March 31, 2013 and December 31, 2012;
•
oil inventory decreased by approximately $7,000 between March 31, 2013 and December 31, 2012;
•
realized and unrealized derivative gains receivable decreased by approximately $43,000 between March 31, 2013 and December 31, 2012; and
•
amounts due to Managing General Partner-other, net, excluding natural gas, NGLs and crude oil sales received from third parties and realized derivative gains, decreased by approximately $7,000 between March 31, 2013 and December 31, 2012.

Additional Development Plan activities, which would include investments in equipment and services to complete refracturing and recompletion opportunities, are suspended until pipeline capacity improves. If the Additional Development Plan commences, funding will be provided by the withholding of distributable cash flows from the Managing General Partner and Investor Partners. Future working capital balances are expected to fluctuate by increasing during periods of Additional Development Plan funding and decreasing during periods when payments are made for refracturing or recompletion activities.


- 19-
PDC 2002-B Limited Partnership
(A West Virginia Limited Partnership)


Cash Flows

Operating Activities

This Partnership's cash flows from operating activities are primarily impacted by commodity prices, production volumes, realized gains and losses from derivative positions, operating costs and direct costs-general and administrative expenses. The key components for the changes in this Partnership's cash flows from operating activities are described in more detail in Results of Operations above.

Net cash flows from operating activities were approximately $7,000 for the three months ended March 31, 2013 compared to approximately $10,000 for the comparable period in 2012. The increase of approximately $3,000 in cash from operating activities was due primarily to the following:

•
a decrease in natural gas, NGLs and crude oil sales receipts of approximately $61,000;
•
an increase in commodity price risk management realized gain receipts of approximately $4,000; and
•
a decrease in production costs and direct costs-general and administrative payments of approximately $54,000.

Investing Activities

From time to time, this Partnership invests in equipment which supports treatment, delivery and measurement of natural gas, NGLs and crude oil or environmental protection. There were no investing activities for the three months ended March 31, 2013. These amounts were not significant during the three months ended March 31, 2012.

Financing Activities

This Partnership initiated monthly cash distributions to investors in March 2003 and has distributed $9.5 million through March 31, 2013. The table below presents cash distributions to this Partnership's investors. Distributions to the Managing General Partner represent amounts distributed to the Managing General Partner for its 20% general partner interest in this Partnership and Investor Partner distributions include amounts distributed to Investor Partners for their 80% ownership share in this Partnership, as well as amounts distributed to the Managing General Partner for limited partnership units repurchased.
Distributions
 
 
 
 
 
 
 
Three months ended March 31,
 
Managing General Partner
 
Investor Partners
 
Total
2013
 
$
527

 
$
6,707

 
$
7,234

2012
 
950

 
8,449

 
9,399


Three months ended March 31, 2013 as compared to three months ended March 31, 2012

The decrease in total distributions for the three months ended March 31, 2013 as compared to 2012 is primarily due to a decrease in cash flows from operating activities during 2013.

Beginning in November 2009, when the Investor Partners' average annual rate of return fell below 12.8%, this Partnership modified the standard ownership-based pro-rata allocation of Partnership cash available for distribution, pursuant to the Performance Standard Obligation outlined in Section 4.02 of the Agreement. Distributions paid to the Managing General Partner were reduced and distributions to the Investor Partners were increased by $668 and $929 for the three months ended March 31, 2013 and 2012, respectively, as a result of the Preferred Cash Distribution made under the terms in Section 4.02. The performance obligation allocation rate modifications continued until February 2013, when the provision expired under the terms of the Agreement.

Off-Balance Sheet Arrangements

As of March 31, 2013, this Partnership had no existing off-balance sheet arrangements, as defined under SEC rules, which have or are reasonably likely to have a material current or future effect on this Partnership's financial condition, results of operations, liquidity, capital expenditures or capital resources.


- 20-
PDC 2002-B Limited Partnership
(A West Virginia Limited Partnership)


Commitments and Contingencies

See Note 6, Commitments and Contingencies, to the accompanying unaudited condensed financial statements included elsewhere in this report.

Recent Accounting Standards

See Note 2, Recent Accounting Standards, to the accompanying unaudited condensed financial statements included elsewhere in this report.

Critical Accounting Policies and Estimates

The preparation of the accompanying unaudited condensed financial statements in conformity with U.S. GAAP requires management to use judgment in making estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities and the reported amounts of revenue and expenses.

There have been no significant changes to this Partnership's critical accounting policies and estimates or in the underlying accounting assumptions and estimates used in these critical accounting policies from those disclosed in the financial statements and accompanying notes contained in this Partnership's 2012 Form 10-K.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Not applicable.

Item 4. Controls and Procedures

This Partnership has no direct management or officers. The management, officers and other employees that provide services on behalf of this Partnership are employed by the Managing General Partner.

(a)    Evaluation of Disclosure Controls and Procedures

As of March 31, 2013, PDC, as Managing General Partner on behalf of this Partnership, carried out an evaluation, under the supervision and with the participation of the Managing General Partner's management, including the Chief Executive Officer and the Chief Financial Officer, of the effectiveness of the design and operation of this Partnership's disclosure controls and procedures pursuant to Exchange Act Rules 13a-15(e) and 15d-15(e). This evaluation considered the various processes carried out under the direction of the Managing General Partner's disclosure committee in an effort to ensure that information required to be disclosed in the SEC reports that this Partnership files or submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified by the SEC's rules and forms, and that such information is accumulated and communicated to this Partnership's management, including the Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely discussion regarding required disclosure.

Based on the results of this evaluation, the Managing General Partner's Chief Executive Officer and the Chief Financial Officer concluded that this Partnership's disclosure controls and procedures were effective as of March 31, 2013.

(b)    Changes in Internal Control over Financial Reporting
 
During the three months ended March 31, 2013, PDC, the Managing General Partner, made no changes in this Partnership's internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) of the Exchange Act) that have materially affected or are reasonably likely to materially affect this Partnership's internal control over financial reporting. 

- 21-
PDC 2002-B Limited Partnership
(A West Virginia Limited Partnership)



PART II – OTHER INFORMATION

Item 1.    Legal Proceedings

Neither this Partnership nor PDC, in its capacity as the Managing General Partner of this Partnership, are party to any pending legal proceeding that PDC believes would have a materially adverse effect on this Partnership's business, financial condition, results of operations or liquidity.


Item 1A. Risk Factors

Not applicable.


Item 2.    Unregistered Sales of Equity Securities and Use of Proceeds

Unit Repurchase Program. Beginning in March 2006, the third anniversary of the date of the first Partnership cash distributions, Investor Partners of this Partnership may request that the Managing General Partner repurchase their respective individual Investor Partner units, up to an aggregate total limit during any calendar year for all requesting Investor Partner unit repurchases, of 10% of the initial subscription units.

The following table presents information about the Managing General Partner's limited partner unit repurchases during the three months ended March 31, 2013:

Period
 
Total Number of
 Units Repurchased
 
Average Price Paid
 Per Unit
January 1 - 31, 2013
 
0.25

 
$
400

February 1 - 28, 2013
 
0.25

 
200

March 1 - 31, 2013
 
0.25

 
200

     Total
 
0.75

 
$
267



Item 3.    Defaults Upon Senior Securities

Not applicable.


Item 4.    Mine Safety Disclosures

Not applicable.


Item 5.    Other Information

None.

- 22-
PDC 2002-B Limited Partnership
(A West Virginia Limited Partnership)



Item 6. Exhibits Index


 
 
 
 
Incorporated by Reference
 
 

Exhibit
Number
 
Exhibit Description
 
Form
 

SEC File
Number
 
Exhibit
 
Filing Date
 

Filed
Herewith
 
 
 
 
 
 
 
 
 
 
 
 
 
10.1
 
Purchase and Sale Agreement by and among PDC Energy, Inc., affiliated partnerships and certain affiliates of Caerus Oil and Gas LLC, dated February 4, 2013.
 
10-Q
 
000-07246
 
10.1
 
5/1/2013
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
31.1
 
Certification by Chief Executive Officer of PDC Energy, Inc., the Managing General Partner of this Partnership, pursuant to Rule 13a-14(a)/15d-14(a) of the Exchange Act Rules, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
 
 
 
 
 
X
 
 
 
 
 
 
 
 
 
 
 
 
 
31.2
 
Certification by Chief Financial Officer of PDC Energy, Inc., the Managing General Partner of this Partnership, pursuant to Rule 13a-14(a)/15d-14(a) of the Exchange Act Rules, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
 
 
 
 
 
X
 
 
 
 
 
 
 
 
 
 
 
 
 
32.1*
 
Certifications by Chief Executive Officer and Chief Financial Officer of PDC Energy, Inc., the Managing General Partner of this Partnership, pursuant to Title 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
 
 
 
 
 
 
 
 
 

 
 
 
 
 
 
 
 
 
 
 
 
 
101.INS*
 
XBRL Instance Document
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
101.SCH*
 
XBRL Taxonomy Extension Schema Document
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
101.CAL*
 
XBRL Taxonomy Extension Calculation Linkbase Document
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
101.DEF*
 
XBRL Taxonomy Extension Definition Linkbase Document
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
101.LAB*
 
XBRL Taxonomy Extension Label Linkbase Document
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
101.PRE*
 
XBRL Taxonomy Extension Presentation Linkbase Document
 
 
 
 
 
 
 
 
 
 

*Furnished herewith.

- 23-
PDC 2002-B Limited Partnership
(A West Virginia Limited Partnership)





SIGNATURES
 
Pursuant to the requirements of Section 13 or 15(d) 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-B Limited Partnership
By its Managing General Partner
PDC Energy, Inc.

 
By: /s/ James M. Trimble
 
 
James M. Trimble
Chief Executive Officer and President
of PDC Energy, Inc.
 
 
May 10, 2013
 
 
 
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the Registrant and in the capacities and on the dates indicated:


Signature
 
Title
Date
 
 
 
 
/s/ James M. Trimble
 
Chief Executive Officer and President
May 10, 2013
James M. Trimble
 
PDC Energy, Inc.
Managing General Partner of the Registrant
 
 
 
(principal executive officer)
 
 
 
 
 
/s/ Gysle R. Shellum
 
Chief Financial Officer
May 10, 2013
Gysle R. Shellum
 
PDC Energy, Inc.
Managing General Partner of the Registrant
 
 
 
(principal financial officer)
 
 
 
 
 
/s/ R. Scott Meyers
 
Chief Accounting Officer
May 10, 2013
R. Scott Meyers
 
PDC Energy, Inc.
Managing General Partner of the Registrant
 
 
 
(principal accounting officer)
 
 

- 24-

PDC 2002 B LTD PARTNERSHIP Reports