CONFORMED COPY
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
[] ANNUAL REPORT PURSUANT TO SECTION 13 or 15 (d) OF
THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 2000
Commission File Number 033-63635-04
[] Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 for the transaction period from to
PDC 1996-D LIMITED PARTNERSHIP
(Exact name of registrant as specified in its charter)
|
West Virginia |
55-0751154 |
|
(State or other jurisdiction of incorporation or organization) |
(I.R.S. Employer Identification No.) |
103 East Main Street, Bridgeport, West Virginia 26330
Address of principal executive offices) (zip code)
Registrant's telephone number, including area code (304) 842-3597
SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT: NONE
SECURITIES REGISTERED PURSUANT TO SECTION 12(g) OF THE ACT:
General and Limited Partnership Interests
(Title of class)
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 and (2) has been subject to such filing requirements for the past 90 days. Yes X No
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will be contained, to the best of registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. [ ]
PART I
ITEM 1. BUSINESS.
General
PDC 1996-D Limited Partnership ("the Partnership") is a limited partnership formed on December 31, 1996 pursuant to the West Virginia Uniform Limited Partnership Act. Petroleum Development Corporation ("PDC") serves as
Managing General Partner of the Partnership.
Since the commencement of operations on December 31, 1996, the Partnership has been engaged in onshore, domestic gas exploration exclusively in the Northern Appalachian and Michigan Basins. A total of 9 limited partners
contributed initial capital of $324,250; a total of 921 additional general partners contributed initial capital of $14,977,476; and PDC (Managing General Partner) contributed $3,328,126 in capital as a participant in accordance with contribution
provisions of the Limited Partnership Agreement (the Agreement).
Under the terms of the Agreement, the allocation of revenues is as follows:
|
|
Allocation of Revenues |
|
Additional General and Limited Partners |
|
|
Managing General Partner |
20% |
Operating and direct costs are allocated and charged to the additional general and limited partners and the Managing General Partner in the same percentages as revenues are allocated. Leasehold, drilling and completion costs, and equipment costs are borne 80% by the additional general and limited partners and 20% by the Managing General Partner.
Employees
The Partnership has no employees, however, PDC has approximately 86 employees which include a staff of geologists, petroleum engineers, landmen and accounting personnel who administer all of the partnership's operations.
Plan of Operations
The Partnership participated in the drilling of 85 gross wells and will continue to operate and produce its 80 gross productive wells. The Partnership does not have unexpended initial capital and no additional drilling activity is planned.
See Item 2 herein for information concerning the Partnership's gas wells.
Markets for Oil and Gas
The availability of a market for any oil and gas produced from the operations of the Partnership will depend upon a number of factors beyond the control of the Partnership which cannot be accurately predicted. These factors include the proximity of the Partnership wells to and the capacity of natural gas pipelines, the availability and price of competitive fuels, fluctuations in seasonal supply and demand, and government regulation of supply and demand created by its pricing and allocation restrictions.
2
Oversupplies of gas can be expected to occur from time to time and may result in the Partnership's wells being shut-in or curtailed. Increased imports of oil and natural gas have occurred and are expected to continue. The effects of such imports could adversely impact the market for domestic oil and natural gas.
Derivatives and Hedging Activities
The Managing General Partner utilizes commodity based derivative instruments as hedges to manage a portion of its and various limited partnerships' exposure to price volatility stemming from natural gas production and marketing activities. These instruments consist of natural gas futures and option contracts traded on the New York Mercantile Exchange. The futures and option contracts hedge committed and anticipated natural gas purchases and 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 and permits utilization of hedges only if there is an underlying physical position.
The Managing General Partner has extensive experience with the use of financial hedges to reduce the risk and impact of natural gas price changes. These hedges are used to coordinate fixed and variable priced purchases and sales and to "lock in" fixed prices from time to time for the Managing General Partner and its various limited partnerships' share of production. In order for future contracts to serve as effective hedges, there must be sufficient correlation to the underlaying hedged transaction. While hedging can help provide price protection if spot prices drop, hedges can also limited upside potential.
Despite the measure taken by the Managing General Partner to attempt to control price risk, the Partnership remains subject to price fluctuations for natural gas sold in the spot market. The Managing General Partner continues to evaluate the potential for reducing these risks by entering into hedge transactions. In addition, the Managing General Partner may also close out any portion of hedges that may exist from time to time.
Competition
The Partnership competes in marketing its gas with numerous companies and individuals, many of which have financial resources, staffs and facilities substantially greater than those of the Partnership or Petroleum Development Corporation.
State Regulations
State regulatory authorities have established rules and regulations requiring permits for well operations, reclamation bonds and reports concerning operations. States also have statutes and regulations concerning the spacing of wells, environmental matters and conservation, and have established regulations concerning the unitization and pooling of oil and gas properties and maximum rates of production from oil and gas wells. The Partnership believes it has complied in all material respects with applicable state regulations.
3
Federal Regulations
Regulation of Liquid Hydrocarbons. Liquid hydrocarbons (including crude oil and natural gas liquids) were subject to federal price and allocation controls until January 1981 when controls were effectively eliminated by executive order of the President. As a result, to the extent the Partnership sells oil produced from its properties, those sales are at unregulated market prices.
Although it appears unlikely under present circumstances that controls will be reimposed upon liquid hydrocarbons, it is possible Congress may enact such legislation at a future date. The impact of such legislation on the Partnership would be minimal since the partnership expects to sell only small quantities of liquid hydrocarbons, if any.
Natural Gas Regulation. Sale of natural gas by the Partnership is subject to regulation of production, transportation and pricing by governmental regulatory agencies. Generally, the regulatory agency in the state where a producing well is located regulates production activities and, in addition, the transportation of gas sold intrastate. The Federal Energy Regulatory Commission (FERC) regulates the operation and cost of interstate pipeline operators who transport gas. Currently the price of gas to be sold by the Partnership is not regulated by any state or federal agency.
The FERC has adopted major changes in certain of its regulations and continues to make additional changes that will significantly affect future transportation and marketing of natural gas.
The Partnership is uncertain how the recent or proposed regulations will affect the marketing of its gas because it is unable to predict how all interstate pipelines that receive its gas will respond to such rulemakings.
Proposed Regulation. Numerous proposals concerning energy are being considered by the United States Congress, various state legislatures and regulatory agencies. The possible outcome and effect of these proposals cannot be accurately predicted.
Environmental and Safety Regulation. The Partnership believes that it complies, in all material respects, with all legislation and regulations affecting its operations in the drilling and production of oil and gas wells and the discharge of wastes. To date, compliance with such provisions and regulations has not had a material effect upon the Partnership's expenditures for capital equipment, its operations or its competitive position. The cost of such compliance is not anticipated to be material in the future.
4
ITEM 2. PROPERTIES.
Drilling Activity
The following table sets forth the results of drilling activity from December 31, 1996 (date of inception) to March 15, 2001, of the Partnership which was conducted in the Continental United States.
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Development Wells |
|||||
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Gross |
Net |
||||
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|
Productive |
Dry |
Total |
Productive |
Dry |
Total |
|
Period Ended March 15, 2001 |
80 |
5 |
85 |
62.474 |
4.912 |
67.386 |
The Partnership has not participated in any exploratory wells. No additional drilling activity is planned.
Summary of Productive Wells
The table below shows the number of the Partnership's gross and net wells by state as of March 15, 2001.
|
Natural Gas Wells |
||
|
Location |
Gross |
Net |
|
Michigan |
21 |
8.466 |
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Pennsylvania |
47 |
42.098 |
|
West Virginia |
12 |
11.910 |
|
|
____ |
______ |
|
Total |
80 |
62.474 |
A "productive well" is a well producing, or capable of producing, oil and gas in commercial quantities. For purposes of the above table, a "gross well" is one in which the Partnership has a working interest and a "net well" is a gross well multiplied by the Partnership's working interest to which it is entitled under its drilling agreement.
Title to Properties
The Partnership's interests in producing acreage are in the form of assigned direct interests in leases. Such properties are subject to customary royalty interests generally contracted for in connection with the acquisition of properties and could be subject to liens incident to operating agreements, liens for current taxes and other burdens. The Partnership believes that none of these burdens materially interfere with the use of such properties in the operation of the Partnership's business.
As is customary in the oil and gas industry, little or no investigation of title is made at the time of acquisition of undeveloped properties (other than a preliminary review of local mineral records). Investigations are generally made, including in most cases receiving a title opinion of legal counsel, before commencement of drilling operations. A thorough examination of title has been made with respect to all of the Partnership's producing properties and the Partnership believes that it has generally satisfactory title to such properties.
ITEM 3. LEGAL PROCEEDINGS.
The Managing General partner as driller/operator is not party to any legal action what would materially affect the Managing General Partner's or Partnership's operations or financial statements.
5
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS.
None.
PART II
ITEM 5. MARKET FOR THE REGISTRANT'S COMMON EQUITY AND SECURITY HOLDER MATTERS.
At December 31, 1996, PDC 1996-D Limited Partnership had one Managing General Partner, 9 Limited Partners who fully paid for 16.2125 units at $20,000 per unit of limited partnership interests and a total of 921 Additional General Partners who fully paid for 748.8738 units at $20,000 per unit of additional general partnership interests. No established public trading market exists for the interests.
Limited and additional general partnership interests are transferable, however no assignee of an interest in the Partnership can become a substituted partner without the written consent of the transferor and the Managing General Partner.
ITEM 6. SELECTED FINANCIAL DATA.
The selected financial data presented below has been derived from audited financial statements of the Partnership appearing elsewhere herein.
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Years Ended December 31, |
||||
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|
2000 |
1999 |
1998 |
||
|
Oil and Gas Sales |
$1,103,647 |
1,060,772 |
1,575,520 |
||
|
Costs and Expenses |
854,895 |
2,457,347 |
9,822,499 |
||
|
Net Income (loss ) |
253,429 |
(1,392,064) |
(8,239,198) |
||
|
Allocation of Net Income (loss): |
|||||
|
Managing General Partner |
50,686 |
(278,413) |
(1,802,037) |
||
|
Limited and Additional |
|
|
|
||
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Per Limited and Additional |
|
|
|
||
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Total Assets |
4,158,775 |
4,536,343 |
6,539,219 |
||
|
Distributions: |
|||||
|
Managing General Partner |
31,728 |
49,205 |
111,388 |
||
|
Limited and Additional |
|
|
|
||
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS.
Liquidity and Capital Resources
The Partnership was funded with initial Limited and Additional General Partner contributions of $15,301,726 and the Managing General Partner contributed $3,328,126 in accordance with the Agreement. Syndication and management fee costs of $1,989,224 were incurred leaving available capital of $16,640,628 for Partnership activities.
The Partnership began exploration and development activities subsequent to the funding of the Partnership and completed these activities by December 31, 1997. Eighty-five wells have been drilled, eighty of which have been completed as producers. No additional wells will be drilled.
6
The Partnership had net working capital at December 31, 2000 of $174,139.
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
2000 Compared to 1999
Oil and gas sales increased 4.04% in 2000 compared to 1999 as a result of an increase in average gas prices offset in part by lower sales volumes of natural gas. Cash distributions increased from $595,117 in 1999 to $625,343 in 2000.
1999 Compared to 1998
Oil and gas sales decreased 32.7% in 1999 compared to 1998 as a result of lower sales volumes of natural gas and lower average sales prices. The net loss of $1,392,064 in 1999 was primarily due to the impairment charge for oil and gas properties. This impairment resulted from net capitalized costs exceeding estimated undiscounted future net cash flow. The impairment was based on estimated fair value which considered future discounted cash flows. This charge did not affect cash distributions to the partners which decreased from $1,327,926 in 1998 to $595,117 in 1999.
The Partnership's revenues from natural gas sales will be affected by changes in prices. Natural gas prices are subject to general market conditions which drive the pricing changes.
The principal effects of inflation upon the Partnership relate to the costs required to drill, complete and operate oil and gas wells. The Partnership expects these costs to remain somewhat stable over the next year.
New Accounting Standards
Statement of Accounting Standards No. 133 and No. 138, Accounting for Derivative Instruments and Hedging Activities (SFAS No. 133/138), was issued by the Financial Accounting Standards Board. SFAS No. 133/138 standardized the accounting for derivative instruments, including certain derivative instruments embedded in other contracts. The Partnership is required to adopt the provisions of SFAS 133/138 effective January 1, 2001. On adoption, the provisions of SFAS No. 133/138 must be applied prospectively. The natural gas futures and options discussed in the Summary of Significant Accounting Policies under Derivatives and Financial Instruments are derivatives pursuant to SFAS 133/138. The Partnership's derivatives will be treated as hedges of committed and/or anticipated transactions and have a total estimated fair value of $(804,251) on December 31, 2000. On January 1, 2001, the Partnership will record this estimated fair value as a liability with a corresponding adjustment to accumulated other comprehensive income (AOCI).
7
Item 7.a. Quantitative and Qualitative Disclosure About Market 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
The Managing General Partner of the Partnership utilizes commodity-based derivative instruments as hedges to manage a portion of its exposure to price risk from its natural gas sales. These instruments consist of NYMEX-traded natural gas futures contracts and option contracts. These hedging arrangements have the effect of locking in for specified periods (at predetermined prices or ranges of prices) the prices the Partnership will receive for the volume to which the hedge relates. As a result, while these hedging arrangements are structured to reduce the Partnership's exposure to decreases in price associated with the hedging commodity, they also limit the benefit the Partnership might otherwise have received from price increases associated with the hedged commodity. The Partnership's policy prohibits the use of natural gas future and option contracts for speculative purposes. As of December 31, 2000, the Partnership had entered into a series of natural gas future contracts and options contracts. Open future contracts maturing in 2001 are for the sale of 186,998 dt of natural gas with a weighted average price of $3.82 dt resulting in a total contract amount of $557,347, and a fair market value of $(721,286). Open option contracts maturing in 2001 are for the sale of 249,331 dt with a weighted average floor price of $3.68 dt and a fair value of $(82,965).
Disclosure of Limitations
As the information above incorporates only those exposures that exist at December 31, 2000, 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 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA:
The response to this Item is set forth herein in a separate section of this Report, beginning on Page F-1.
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE.
NONE.
8
Part III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE COMPANY.
The Partnership has no directors or executive officers. The Partnership is managed by Petroleum Development Corporation (the Managing General Partner). Petroleum Development Corporation's common stock is traded in the NASDAQ National Market and Form 10-K for 1999 has been filed with the Securities and Exchange Commission.
ITEM 11. MANAGEMENT REMUNERATIONS AND TRANSACTIONS.
NON-APPLICABLE.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT.
NON-APPLICABLE.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS.
Pursuant to the authorization contained in the Limited Partnership Agreement, PDC receives fees for services rendered and reimbursement of certain expenses from the Partnership. The following table presents compensation or reimbursements by the Partnership to PDC or other related parties during the years listed below:
|
Years Ended December 31, |
|||
|
|
2000 |
1999 |
1998 |
|
Lifting costs |
$460,375 |
458,641 |
450,400 |
|
Tax return preparation |
10,250 |
10,320 |
10,260 |
|
Direct administrative cost |
2,618 |
(689) |
2,526 |
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K.
(a) (1) Financial Statements
See Index to Financial Statements on F-2
(2) Financial Statement Schedules
See Index to Financial Statements on page F-2. All financial statement schedules are omitted because they are not required, inapplicable, or the information is included in the Financial Statements or Notes thereto.
9
CONFORMED COPY
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.
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PDC 1996-D Limited Partnership |
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By its Managing General Partner Petroleum Development Corporation |
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By /s/ James N. Ryan James N. Ryan, Chairman |
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March 26, 2001 |
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:
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Signature |
Title |
Date |
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|
||
|
/s/ James N. Ryan James N. Ryan |
Chairman, Chief Executive Officer and Director |
March 26, 2001 |
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/s/ Steven R. Williams Steven R. Williams |
President and Director |
March 26, 2001 |
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/s/ Dale G. Rettinger Dale G. Rettinger |
Executive Vice President, Treasurer and Director (principal financial and accounting officer) |
March 26, 2001 |
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/s/ Roger J. Morgan Roger J. Morgan |
Secretary and Director |
March 26, 2001 |
10
PDC 1996-D LIMITED PARTNERSHIP
(A West Virginia Limited Partnership)
Financial Statements for Annual Report
on Form 10-K to Securities and Exchange
Commission
Years Ended December 31, 2000, 1999 and 1998
(With Independent Auditors' Report Thereon)
F-1
PDC 1996-D LIMITED PARTNERSHIP
(A West Virginia Limited Partnership)
Index to Financial Statements
|
Independent Auditors' Report |
F-3 |
|
Balance Sheets - December 31, 2000 and 1999 |
F-4 |
|
Statements of Operations - Years Ended December 31, 2000, 1999 and 1998 |
|
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Statements of Partners' Equity - Years Ended December 31, 2000, 1999 and 1998 |
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Statements of Cash Flows - Years Ended December 31, 2000, 1999 and 1998 |
|
|
Notes to Financial Statements |
F-8 |
All financial statement schedules have been omitted because they are not applicable or not required or for the reason that the required information is shown in the financial statements or notes thereto.
F-2
Independent Auditors' Report
To the Partners
PDC 1996-D Limited Partnership:
We have audited the financial statements of PDC 1996-D Limited Partnership (a West Virginia limited partnership) as listed in the accompanying index. These financial statements are the responsibility of the Partnership's management. Our responsibility is to express an opinion on these financial statements based on our audits.
We conducted our audits in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of PDC 1996-D Limited Partnership as of December 31, 2000 and 1999, and the results of its operations and its cash flows for the years ended December 31, 2000, 1999 and 1998, in conformity with accounting principles generally accepted in the United States of America.
KPMG LLP
Pittsburgh, Pennsylvania
March 26, 2001
F-3
PDC 1996-D LIMITED PARTNERSHIP
(A West Virginia Limited Partnership)
Balance Sheets
December 31, 2000 and 1999
|
Assets |
2000 |
1999 |
|
Current assets: |
||
|
Cash |
$ 4,732 |
2,017 |
|
Accounts receivable - oil and gas revenues |
|
|
|
Total current assets |
199,861 |
207,128 |
|
Oil and gas properties, successful efforts method (Notes 3 and 5): |
|
|
|
Less accumulated depreciation, depletion, and amortization |
|
|
|
3,958,914 |
4,329,215 |
|
|
$4,158,775 |
4,536,343 |
|
|
Current Liabilities and Partners' Equity |
||
|
Current liabilities: |
||
|
Accrued expenses |
$ 25,722 |
31,376 |
|
Total current liabilities |
25,722 |
31,376 |
|
Partners' equity |
4,133,053 |
4,504,967 |
|
$4,158,775 |
4,536,343 |
|
|
|
See accompanying notes to financial statements.
F-4
PDC 1996-D LIMITED PARTNERSHIP
(A West Virginia Limited Partnership)
Statements of Operations
Years Ended December 31, 2000, 1999 and 1998
|
2000 |
1999 |
1998 |
|
|
Revenues: |
|||
|
Sales of oil and gas |
$ 1,103,647 |
1,060,772 |
1,575,520 |
|
Interest income |
4,677 |
4,511 |
7,781 |
|
1,108,324 |
1,065,283 |
1,583,301 |
|
|
Expenses (note 3): |
|||
|
Lifting cost |
460,375 |
458,641 |
450,400 |
|
Independent audit fee |
7,163 |
6,954 |
7,320 |
|
Franchise taxes |
4,188 |
3,960 |
5,938 |
|
Tax return preparation |
10,250 |
10,320 |
10,260 |
|
Direct administrative cost |
2,618 |
(689) |
2,526 |
|
Independent engineering cost |
- |
- |
5,032 |
|
Loss on impairment of oil and gas properties |
|
|
|
|
Depreciation, depletion and amortization |
|
|
|
|
854,895 |
2,457,347 |
9,822,499 |
|
|
Net income (loss) |
$ 253,429 |
(1,392,064 ) |
(8,239,198 ) |
|
Net income (loss) per limited and additional general partner unit |
|
|
|
See accompanying notes to financial statements.
F-5
PDC 1996-D LIMITED PARTNERSHIP
(A West Virginia Limited Partnership)
Statements of Partners' Equity
Years Ended December 31, 2000, 1999 and 1998
|
Limited and additional general partners |
general partner |
|
|
|
Balance, December 31, 1997 |
$12,847,417 |
3,211,855 |
16,059,272 |
|
Net loss |
(6,437,161) |
(1,802,037) |
(8,239,198) |
|
Distributions to partners |
(1,216,538 ) |
(111,388 ) |
(1,327,926 ) |
|
Balance, December 31, 1998 |
5,193,718 |
1,298,430 |
6,492,148 |
|
Net loss |
(1,113,651) |
(278,413) |
(1,392,064) |
|
Distributions to partners |
(545,912 ) |
(49,205 ) |
(595,117 ) |
|
Balance, December 31, 1999 |
3,534,155 |
970,812 |
4,504,967 |
|
Net income |
202,743 |
50,686 |
253,429 |
|
Distributions to partners |
(593,615 ) |
(31,728 ) |
(625,343 ) |
|
Balance, December 31, 2000 |
$ 3,143,283 |
989,770 |
4,133,053 |
See accompanying notes to financial statements.
F-6
PDC 1996-D LIMITED PARTNERSHIP
(A West Virginia Limited Partnership)
Statements of Cash Flows
Years Ended December 31, 2000, 1999 and 1998
|
2000 |
1999 |
1998 |
|
|
Cash flows from operating activities: |
|||
|
Net income (loss) |
$ 253,429 |
(1,392,064) |
(8,239,198) |
|
Adjustments to reconcile net income (loss) to net cash provided from operating activities: |
|||
|
Depreciation, depletion and amortization |
370,301 |
619,127 |
1,530,963 |
|
Loss on impairment of oil and gas properties |
- |
1,359,034 |
7,810,060 |
|
Changes in operating assets and liabilities: |
|||
|
Decrease in accounts receivable - oil and gas revenues |
|
|
|
|
(Decrease) increase in accrued expenses |
|
|
|
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Net cash provided from operating activities |
|
|
|
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Cash flows from financing activities: |
|||
|
Distributions to partners |
(625,343 ) |
(595,117 ) |
(1,327,926 ) |
|
Net cash used by financing activities |
|
|
|
|
Net increase (decrease) in cash |
2,715 |
(4,695) |
3,956 |
|
Cash at beginning of period |
2,017 |
6,712 |
2,756 |
|
Cash at end of period |
$ 4,732 |
2,017 |
6,712 |
See accompanying notes to financial statements.
F-7
PDC 1996-D LIMITED PARTNERSHIP
(A West Virginia Limited Partnership)
Notes to Financial Statements
Years Ended December 31, 2000, 1999 and 1998
(1) Summary of Significant Accounting Policies
Partnership Financial Statement Presentation Basis
The financial statements include only those assets, liabilities and results of operations of the partners which relate to the business of PDC 1996-D Limited Partnership (the Partnership). The statements do not include any assets, liabilities, revenues or expenses attributable to any of the partners' other activities.
Oil and Gas Properties
The Partnership follows the successful efforts method of accounting for the cost of exploring for and developing oil and gas reserves. Under this method, costs of development wells, including equipment and intangible drilling costs related to both producing wells and developmental dry holes, and successful exploratory wells are capitalized and amortized on an annual basis to operations by the units-of-production method using estimated proved developed reserves determined at year-end by an independent petroleum engineer, Wright & Company, Inc., in 1998 and by the Managing General Partner's petroleum engineers in 1999 and 2000. If a determination is made that an exploratory well has not discovered economically producible reserves, then its costs are expensed as dry hole costs.
The Partnership assesses impairment of capitalized costs of proved oil and gas properties by comparing net capitalized costs to undiscounted future net cash flows on a field-by-field basis using expected prices. Prices utilized in each year's calculation for measurement purposes and expected costs are held constant. 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. During 2000, 1999 and 1998 the loss on impairment of oil and gas properties as reflected in the statement of operations amounted to $0, $1,359,034 and $7,810,600, respectively.
Based on the Managing General Partner's experience, management believes site restoration, dismantlement and abandonment costs, net of salvage to be immaterial in relation to operating costs. These costs are being expensed when incurred.
Income Taxes
Since the taxable income or loss of the Partnership is reported in the separate tax returns of the partners, no provision has been made for income taxes on the Partnership's books.
(Continued)
F-8
PDC 1996-D LIMITED PARTNERSHIP
(A West Virginia Limited Partnership)
Notes to Financial Statements, Continued
Under federal income tax laws, regulations and administrative rulings, certain types of transactions may be accorded varying interpretations. Accordingly, the Partnership's tax return and, consequently, individual tax returns of the partners may be changed to conform to the tax treatment resulting from a review by the Internal Revenue Service.
Derivatives Financial Instruments
The Managing General Partner utilizes commodity based derivative instruments as hedges to manage a portion of its and various limited partnerships' exposure to price volatility stemming from natural gas production. These instruments consist of natural gas futures and option contracts traded on the New York Mercantile Exchange. The futures and option contracts hedge committed and anticipated natural gas sales generally forecasted to occur within a 12 month period. The Partnership does not hold or issue derivatives for trading or speculative purposes.
As of December 31, 2000 the Partnership had futures contracts for the sale of 186,998 dt of natural gas and option contracts for the sale of 249,331 dt of natural gas. While these contracts have nominal carrying value, their fair value, represented by the estimated amount that would be received (paid) upon termination of the contracts, based on market quotes, was a fair value of $(804,251). Gains and losses related to qualifying hedges of firm commitments or anticipated transactions through the use of natural gas futures and option contracts are deferred and recognized in income or as adjustments of carrying amounts when the underlying hedged transaction occurs. In order for futures contracts to qualify as a hedge, there must be sufficient correlation to the underlying hedged transaction. The change in the fair value of derivative instruments which do not qualify for hedging are recognized into income currently.
Use of Estimates
Management of the Partnership has made a number of estimates and assumptions relating to the reporting of assets and liabilities and revenues and expenses and the disclosure of contingent assets and liabilities to prepare these financial statements in conformity with generally accepted accounting principles. Actual results could differ from those estimates. Estimates which are particularly significant to the financial statements include estimates of oil and gas reserves and future cash flows from oil and gas properties.
F-9
PDC 1996-D LIMITED PARTNERSHIP
(A West Virginia Limited Partnership)
Notes to Financial Statements, Continued
New Accounting Standards
Statement of Accounting Standards No. 133 and No. 138, Accounting for Derivative Instruments and Hedging Activities (SFAS No. 133/138), was issued by the Financial Accounting Standards Board. SFAS No. 133/138 standardized the accounting for derivative instruments, including certain derivative instruments embedded in other contracts. The Partnership is required to adopt the provisions of SFAS 133/138 effective January 1, 2001. On adoption, the provisions of SFAS No. 133/138 must be applied prospectively. The natural gas futures and options discussed in the Summary of Significant Accounting Policies under Derivatives and Financial Instruments are derivatives pursuant to SFAS 133/138. The Partnership's derivatives will be treated as hedges of committed and/or anticipated transactions and have a total estimated fair value of $(804,251) on December 31, 2000. On January 1, 2001, the Partnership will record this estimated fair value as a liability with a corresponding adjustment to accumulated other comprehensive income (AOCI).
(2) Organization
The Partnership was organized as a limited partnership on December 31, 1996 in accordance with the laws of the State of West Virginia for the purpose of engaging in the drilling, completion and operation of oil and gas development and exploratory wells in the Northern Appalachian and Michigan Basins.
Purchasers of partnership units subscribed to and fully paid for 16.2125 units of limited partner interests and 748.8738 units of additional general partner interests at $20,000 per unit (Investor Partners). Petroleum Development Corporation has been designated the Managing General Partner of the Partnership. Although costs, revenues and cash distributions allocable to the limited and additional general partners are shared pro rata based upon the amount of their subscriptions, including the Managing General Partner to the extent of its capital contributions, there are significant differences in the federal income tax effects and liability associated with these different types of units in the Partnership.
In accordance with the terms of the Partnership Agreement (the Agreement), the Managing General Partner manages all activities of the Partnership and acts as the intermediary for substantially all Partnership transactions.
F-10
PDC 1996-D LIMITED PARTNERSHIP
(A West Virginia Limited Partnership)
Notes to Financial Statements, Continued
(3) Transactions with Managing General Partner and Affiliates
The Partnership's transactions with the Managing General Partner include charges for the following:
|
Years Ended December 31, |
|||
|
2000 |
1999 |
1998 |
|
|
Lifting costs |
$460,375 |
458,641 |
450,400 |
|
Tax return preparation |
10,250 |
10,320 |
10,260 |
|
Direct administrative cost |
2,618 |
(689) |
2,526 |
(4) Allocation
The following table summarizes the participation of the Managing General Partner and the Investor Partners, taking account of the Managing General Partner's capital contribution equal to a minimum of 20% of the Initial Operating Capital, in the costs and revenues of the Partnership.
|
Partners |
Managing General Partner |
|
|
Costs |
||
|
Broker-dealer Commissions and Expenses(1) |
100% |
0% |
|
Management Fee |
100% |
0% |
|
Undeveloped Lease Costs |
0% |
100% |
|
Drilling and Completion Costs |
80% |
20% |
|
Tangible Equipment |
0% |
100% |
|
Intangible Drilling and Development Costs |
100% |
0% |
|
Operating Costs(2) |
80% |
20% |
|
Direct Costs(3) |
80% |
20% |
|
Administrative Costs |
0% |
100% |
|
Partnership Revenues |
||
|
Sale of Oil and Gas Production(4) |
80% |
20% |
|
Sale of Productive Properties(5) |
80% |
20% |
|
Sale of Equipment |
0% |
100% |
|
Sale of Undeveloped Leases |
80% |
20% |
|
Interest Income |
80% |
20% |
(1) Organization and Offering Costs, net of the Dealer Manager commissions, discounts, due diligence expenses, and wholesaling fees of the Partnership were paid by the Managing General Partner and not from Partnership funds. In addition, Organization and Offering Costs in excess of 10-1/2% of Subscriptions were paid by the Managing General Partner, without recourse to the Partnership.
(2) Represents Operating costs incurred after the completion of productive wells, including monthly per-well charges paid to the Managing General Partner.
F-11
PDC 1996-D LIMITED PARTNERSHIP
(A West Virginia Limited Partnership)
Notes to Financial Statements, Continued
(3) The Managing General Partner receives monthly reimbursement from the Partnership for their direct costs incurred by the Managing General Partner on behalf of the Partnership.
(4) The revenues and expenses allocated to the partners are subject to a special provision in the partnership agreement, whereby the allocable share of revenues and expenses of the Investor Partners may be increased and the interest of the Managing General Partner may be decreased if certain cash distribution levels are not met. The shifting of the allocable share of revenues and expenses to the Investor Partners in the event that certain prescribed cash distribution levels are not attained may also serve to shift an increased amount of cash distributions to the Investor Partners and a decreased amount of cash distributions to the Managing General Partner.
(5) In the event of the sale or other disposition of a productive well, a lease upon which such well is situated, or any equipment related to any such lease or well, the proceeds from such sale or disposition shall be allocated and credited to the Partners as oil and gas revenues are allocated. The term "proceeds" above does not include revenues from a royalty, overriding royalty, lease interest reserved, or other promotional consideration received by the Partnership in connection with any sale or disposition, which revenues shall be allocated to the Investor Partners and the Managing General Partner in the same percentages that oil and gas revenues are allocated. No such sales have occurred.
(6) In accordance with the repurchase provision of the partnership prospectus, PDC repurchases units from the investing partners which is entirely voluntary on the part of the partners. During 2000 PDC purchased a total of 11.50 units of partnership interest for a total ownership of 11.50 units as of December 31, 2000 which represents a 1.12% ownership of the Investor Partners share of limited and additional general partnership units. Therefore, costs and revenues and distributions for these purchased units are allocated to PDC in accordance with the Investor Partners allocation percentages disclosed in this table.
(5) Costs Relating to Oil and Gas Activities
The Partnership is engaged solely in oil and gas activities, all of which are located in the continental United States. Information regarding aggregate capitalized costs and results of operations for these activities is located in the basic financial statements. Costs capitalized for these activities are as follows:
|
December 31, |
|||
|
2000 |
1999 |
1998 |
|
|
Lease acquisition costs |
$ 535,823 |
535,823 |
535,823 |
|
Intangible development costs |
13,632,238 |
13,632,238 |
13,632,238 |
|
Well equipment |
2,452,567 |
2,452,567 |
2,452,567 |
|
Impairment charge |
(9,169,094 ) |
(9,169,094 ) |
(7,810,060 ) |
|
$7,451,534 |
7,451,534 |
8,810,568 |
|
F-12
PDC 1996-D LIMITED PARTNERSHIP
(A West Virginia Limited Partnership)
Notes to Financial Statements, Continued
There were no costs incurred for the Partnership's oil and gas activities for the years ended December 31, 2000, 1999 and 1998.
(6) Income Taxes
As a result of the differences in the treatment of certain items for income tax purposes as opposed to financial reporting purposes, primarily depreciation, depletion and amortization of oil and gas properties and the recognition of intangible drilling costs as an expense or capital item, the income tax basis of oil and gas properties differs from the basis used for financial reporting purposes. At December 31, 2000 and 1999, the income tax basis of the partnership's oil and gas properties was $1,519,216 and $1,764,354, respectively.
(7) Supplemental Reserve Information (Unaudited)
Proved oil and gas reserves of the Partnership have been estimated by the Managing General Partner's petroleum engineers at December 31, 2000 and 1999 and by an independent petroleum engineer, Wright & Company, Inc. at December 31, 1998. These reserves have been prepared in compliance with the Securities and Exchange Commission rules based on year-end prices, adjusted for hedging contracts. A copy of the reserve report has been made available to all partners. All of the partnership's reserves are proved developed. An analysis of the change in estimated quantities of proved developed oil and gas reserves is shown below:
|
Natural gas (mcf) |
|
|
Proved developed reserves as of December 31, 1997 |
|
|
Revisions of previous estimates |
(3,412,559) |
|
Production |
(656,385 ) |
|
Proved developed reserves as of December 31, 1998 |
|
|
Revisions of previous estimates |
(3,098,005) |
|
Production |
(483,641 ) |
|
Proved developed reserves as of |
|
|
December 31, 1999 |
4,978,500 |
|
Revisions of previous estimates |
593,473 |
|
Production |
(413,073 ) |
|
Proved developed reserves as of December 31, 2000 |
|
F-13