1
As filed with the Securities and Exchange Commission on April 21, 2000
Registration No. 333-76911
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SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
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POST-EFFECTIVE AMENDMENT NO. 2
TO
FORM S-1
REGISTRATION STATEMENT UNDER THE SECURITIES ACT OF 1933
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MEWBOURNE ENERGY 99-00 DRILLING PROGRAMS, L.P.
MEWBOURNE ENERGY PARTNERS 99-A, L.P.
MEWBOURNE ENERGY PARTNERS 00-A, L.P.
(Exact name of registrants)
DELAWARE 1311
(State or other jurisdiction of (Primary Standard Industrial (I.R.S. Employer Identification No.)
incorporation or organization) Classification Code Number)
3901 S. BROADWAY
TYLER, TEXAS 75701
(903) 561-2900
(Address, including zip code, and telephone number, including
area code, of registrant's principal executive offices)
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COPIES TO:
CURTIS W. MEWBOURNE A. WINSTON OXLEY
MEWBOURNE DEVELOPMENT CORPORATION CHAD ARNETTE
3901 S. BROADWAY VINSON & ELKINS L.L.P.
TYLER, TEXAS 75701 3700 TRAMMELL CROW CENTER
(903) 561-2900 2001 ROSS AVENUE
(Name, address, including zip code, and telephone number, DALLAS, TEXAS 75201
including area code, of agent for service) (214) 220-7700
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APPROXIMATE DATE OF COMMENCEMENT OF PROPOSED SALE TO THE PUBLIC: As soon as
practicable after the effective date of this Registration Statement.
If any of the securities being registered on this form are to be offered on
a delayed or continuous basis pursuant to Rule 415 under the Securities Act of
1933, check the following box. [X]
CALCULATION OF REGISTRATION FEE
=======================================================================================================
PROPOSED PROPOSED
AMOUNT MAXIMUM MAXIMUM AMOUNT OF
TITLE OF SECURITIES TO BE OFFERING PRICE AGGREGATE REGISTRATION
TO BE REGISTERED REGISTERED(1) PER INTEREST(2) OFFERING PRICE(1) FEE(3)
------------------- ------------- --------------- ----------------- ------------
Limited Partner Interests..... 20,000 $1,000 $ 4,000,000 $ 1,112
General Partner Interests..... 16,000 $1,000 $16,000,000 $ 4,448
TOTAL................................................................. $ 5,560(3)
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(1) This registration statement covers all limited partner interests that may
be acquired by limited partners, all general partner interests that may be
acquired by general partners, and 16,000 additional limited partner
interests into which general partner interests are convertible if the
maximum aggregate subscriptions contemplated by this offering are obtained.
No subscriber will be admitted as an investor partner in a partnership
unless, at the end of the subscription period for interests in that
partnership, subscription funds have been received and accepted by
Mewbourne Development Corporation in an amount of $1,000,000 or more and
Mewbourne Development Corporation determines, in its sole discretion, to
proceed with the funding of that partnership.
(2) Subscriptions will be accepted in the minimum amount of five interests
($5,000), subject to certain state law requirements.
(3) Previously paid.
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THE REGISTRANT HEREBY AMENDS THIS REGISTRATION STATEMENT ON SUCH DATE OR
DATES AS MAY BE NECESSARY TO DELAY ITS EFFECTIVE DATE UNTIL THE REGISTRANT SHALL
FILE A FURTHER AMENDMENT WHICH SPECIFICALLY STATES THAT THIS REGISTRATION
STATEMENT SHALL THEREAFTER BECOME EFFECTIVE IN ACCORDANCE WITH SECTION 8(a) OF
THE SECURITIES ACT OF 1933, AS AMENDED, OR UNTIL THE REGISTRATION STATEMENT
SHALL BECOME EFFECTIVE ON SUCH DATE AS THE COMMISSION, ACTING PURSUANT TO SAID
SECTION 8(a), MAY DETERMINE.
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P R O S P E C T U S SUBJECT TO COMPLETION
PRELIMINARY PROSPECTUS DATED
April 21, 2000
MEWBOURNE ENERGY PARTNERS
99-00 DRILLING PROGRAMS
(PER PARTNERSHIP MINIMUM OFFERING AMOUNT)
$1,000,000 (1,000 GENERAL AND/OR LIMITED PARTNER
INTERESTS AT $1,000 PER INTEREST)
Minimum Purchase: 5 Interests ($5,000)
We are offering to qualified investors during 1999 and 2000 an
aggregate of up to 4,000 ($4,000,000) limited partner interests and 16,000
($16,000,000) general partner interests in a series of two Delaware limited
partnerships formed or to be formed by us. We will sell these interests to
investors for $1,000 each. The minimum number of interests that we will offer
for any one partnership is 1,000 and the minimum subscription in any one
partnership is five interests ($5,000). The maximum number of interests that we
will offer for any one partnership is 10,000. Therefore, the minimum offering
amount for any one partnership will be $1,000,000 and the maximum offering
amount for any one partnership will be $10,000,000. If we accept your
subscription for a partnership, you may elect to be admitted as a general
partner or limited partner in the partnership you have invested in. Each
partnership will participate with us and our affiliate, Mewbourne Oil Company,
in a drilling program. The primary objective of each drilling program will be to
establish oil and gas reserves by drilling wells in the Permian and Anadarko
Basins.
SEE "RISK FACTORS" BEGINNING ON PAGE 4 FOR A DISCUSSION OF FACTORS THAT
YOU SHOULD CONSIDER BEFORE YOU INVEST IN EITHER PARTNERSHIP BEING SOLD WITH THIS
PROSPECTUS. These "risk factors" include but are not limited to:
o Drilling to establish productive oil and natural gas properties is
highly risky and includes the possibility of a total loss of one's
investment.
o If you purchase a general partner interest you may be subject to
personal unlimited liability for that partnership's obligations.
o An investment in a partnership is illiquid. You may not be able to sell
any interests you purchase because there will be no market for them.
Per Partnership
------------------------------------------
Per Interest Total Minimum Total Maximum
------------ ------------- -------------
Public Price ...................... $1,000 $1,000,000 $10,000,000
Underwriting Discounts ............ 85 85,000 850,000
Proceeds Available to a partnership 1,000 1,000,000 10,000,000
Neither the Securities and Exchange Commission nor any state securities
commission has approved or disapproved of these securities or passed upon the
adequacy or accuracy of this prospectus. Any representation to the contrary is a
criminal offense.
Soliciting dealers will be soliciting subscriptions on a
"minimum/maximum best efforts" basis. The soliciting dealers must sell the
minimum number of interests offered ($1,000,000) if any interests are sold and
are required to use only their best efforts to sell the maximum number of
securities offered ($10,000,000).
The date of this prospectus is ______________, 2000.
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TABLE OF CONTENTS
Page
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SUMMARY OF OFFERING............................................................................................1
The Partnership.............................................................................................1
Investment Objectives.......................................................................................1
Proposed Activities.........................................................................................2
Application of Proceeds.....................................................................................2
Investment as a Limited Partner or General Partner .........................................................2
Liability of General Partners............................................................................3
Liability of Limited Partners............................................................................3
How to Subscribe.........................................................................................3
RISK FACTORS...................................................................................................4
Particular Risks Relating to the Interests..................................................................4
Liability of Limited Partners............................................................................4
Liability of Investor General Partners...................................................................4
Liability of Joint Working Interest Owners...............................................................4
Possibility of Reduction or Unavailability of Insurance Coverage of a Partnership........................4
Sole Reliance on Us for Management of a Partnership......................................................5
Sole Reliance on Our Financial Status....................................................................5
Prospects Not Yet Identified or Selected; No Opportunity to Evaluate Prospects...........................5
Limited Ability to Spread Risk...........................................................................5
Ownership of Interests in a Partnership by Our Affiliates................................................5
Additional Partnership Financing May Become Necessary Due to Unforeseen Circumstances ...................6
Uncertainty of Partnership Cash Distributions............................................................6
Conflicts of Interest of Managing Partner................................................................6
Inside Board of Directors and Other Family Relationships of Managing Partner and Program Director........7
Limitations on the Fiduciary Obligations of the Managing Partner and the Managing Partner's
Responsibility to Determine the Application of the Limitations........................................7
Partnership's Joint Activities With Others...............................................................8
Lack of Liquidity for Investors..........................................................................8
Indemnification of Managing Partner and its Affiliates...................................................8
Investor's Lack of Substantial Voting Rights.............................................................8
Investor's Lack of Appraisal Rights.....................................................................9
Limited Ability to Remove Managing Partner and Difficulty in Finding a Successor Managing Partner........9
Withdrawal of Partners...................................................................................9
Dissolution of a Partnership and Termination of the Drilling Program.....................................9
Ability of the Managing Partner to Cause Dissolution of a Partnership and the Related Drilling Program...9
Unauthorized Acts of General Partners Could Be Binding Against the Partnership..........................10
General Risks Relating to Oil and Natural Gas Operations...................................................10
Loss of Investment Due to Speculative Nature of Oil and Gas Activities..................................10
The Partnerships and the General Partners Could be Liable for Environmental Hazards.....................10
Return on Investment is Dependent on Future Prices, Supply and Demand for Oil and Gas...................11
Government Regulation of a Partnership's Activities.....................................................11
Tax Risks..................................................................................................11
General.................................................................................................11
Partnership Classification for Tax Purposes; No IRS Ruling Sought.......................................11
Allocations.............................................................................................12
Passive Activity Limitations............................................................................12
Considerations for Tax-Exempt Investors.................................................................13
Tax Shelter Registration................................................................................13
Current Tax Deductions..................................................................................13
Conversion of General Partner Interests.................................................................13
Tax Liabilities in Excess of Cash Distributions.........................................................13
Risks of Borrowings.....................................................................................14
Percentage Depletion....................................................................................14
Farmouts and Backin Interests...........................................................................14
Recapture...............................................................................................14
Audits..................................................................................................14
Changes in Federal Income Tax Laws......................................................................14
Significance of Tax Aspects.............................................................................14
Forward Looking Statements.................................................................................15
APPLICATION OF PROCEEDS.......................................................................................15
PARTICIPATION IN COSTS AND REVENUES...........................................................................18
Costs and Revenues.........................................................................................18
Distributions..............................................................................................18
Capital Accounts...........................................................................................19
Allocations of Federal Income Tax Items....................................................................19
Proportionate Interests of Partners........................................................................19
COMPENSATION AND REIMBURSEMENT................................................................................20
Partnership and Program Interest...........................................................................20
(i)
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Page
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Lease and Equipment Purchases from Mewbourne ..............................................................20
Administrative Costs.......................................................................................21
ESTIMATED DRILLING PROGRAM EXPENSES ..........................................................................22
Contracts with Mewbourne and Its Affiliates................................................................22
Compensation as Operator...................................................................................22
DEFINITIONS...................................................................................................23
TERMS OF THE OFFERING.........................................................................................26
General....................................................................................................26
Subscription Refunds.......................................................................................27
Subscription Period........................................................................................27
Suitability Standards......................................................................................28
General.................................................................................................28
Minimum Suitability Standards...........................................................................28
Additional Suitability Standards........................................................................29
Additional Requirements.................................................................................30
Subscription Procedure.....................................................................................31
Conversion of General Partner Interests....................................................................32
Right of Presentment.......................................................................................32
ADDITIONAL FINANCING..........................................................................................34
General....................................................................................................34
Limitation on Borrowings...................................................................................34
PLAN OF DISTRIBUTION..........................................................................................35
INVESTMENT OBJECTIVES.........................................................................................36
PROPOSED ACTIVITIES...........................................................................................36
Development Policy.........................................................................................37
Area of Geographic Concentration...........................................................................37
Prospect Evaluation........................................................................................38
Cost Estimates.............................................................................................38
Acquisition of Leases......................................................................................38
Transactions with Affiliates...............................................................................38
Sale of Leases to a Partnership.........................................................................38
Purchase of Leases from a Partnership...................................................................40
Participation by Mr. Mewbourne..........................................................................40
Farmouts...................................................................................................41
Operations.................................................................................................42
Title to Partnership Properties............................................................................43
Insurance..................................................................................................43
The Managing Partner's Policy Regarding Roll-Up Transactions...............................................45
MANAGEMENT....................................................................................................47
OWNERSHIP STRUCTURE OF MEWBOURNE COMPANIES....................................................................48
Officers, Directors and Key Employees of the Managing Partner and the Drilling Program Manager.............49
Key Employees..............................................................................................49
Compensation...............................................................................................51
Executive Officer..........................................................................................51
Cash Compensation to Executive Officer..................................................................51
Executive Officer Compensation Under Plans..............................................................52
Non-Cash Compensation of Executive Officer..............................................................52
Certain Transactions.......................................................................................53
Participation in Drilling Program Activities............................................................53
CONFLICTS OF INTEREST.........................................................................................53
Fiduciary Responsibility of the Managing Partner...........................................................53
Limitations on the Fiduciary Obligations of the Managing Partner and the Managing Partner's
Responsibility to Determine the Application of the Limitations.......................................54
Farmouts...................................................................................................55
Purchase of Leases from a Partnership......................................................................56
Sale of Leases to a Partnership............................................................................56
Adjacent Acreage...........................................................................................57
Other Activities...........................................................................................57
Contracts with Mewbourne and Affiliates....................................................................58
Mewbourne Oil Company as Operator..........................................................................58
Ownership of Interests by the Managing Partner or any Affiliates...........................................59
PRIOR ACTIVITIES..............................................................................................59
Prior Partnerships.........................................................................................59
Past Compensation..........................................................................................61
Previous Drilling Activities...............................................................................63
Payout and Net Cash Tables.................................................................................64
Tax Deductions and Tax Credits.............................................................................68
Reserves and Future Net Revenues of Prior Programs.........................................................70
TAX ASPECTS...................................................................................................72
Opinion of Counsel.........................................................................................72
Partnership Taxation.......................................................................................74
General.................................................................................................74
Partnership Classification..............................................................................74
Taxation of Partners....................................................................................76
Allocations.............................................................................................76
Elections and Returns...................................................................................78
Determinations of Partnership Items at Partnership Level................................................78
(ii)
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Administrative Costs....................................................................................79
Conversion of General Partner Interests.................................................................79
Special Features of Oil and Gas Taxation...................................................................79
Lease Acquisition Costs.................................................................................79
Geophysical Costs.......................................................................................80
Operating and Administrative Costs......................................................................80
Intangible Drilling Costs...............................................................................80
Depreciation............................................................................................81
Depletion...............................................................................................81
Passive Activity Loss Limitations.......................................................................81
Limitations on Interest Deductions......................................................................83
For Profit Limitation...................................................................................84
Basis and At Risk Limitations...........................................................................84
Sale of Property........................................................................................85
Termination of a Partnership............................................................................85
Sale of Interests.......................................................................................86
Farmouts and Backin Interests...........................................................................87
General Tax Provisions.....................................................................................87
Other Tax Consequences.....................................................................................87
Alternative Minimum Tax.................................................................................87
Tax Shelter Registration................................................................................88
Changes in Federal Income Tax Laws......................................................................88
Compliance Provisions...................................................................................88
Consistency Requirements................................................................................89
Nominees................................................................................................89
Social Security Benefits; Self-Employment Tax...........................................................89
Investment by Tax-Exempt Entities.......................................................................89
State Law Tax Aspects...................................................................................90
Anticipated Federal Income Tax Deductions..................................................................90
Individual Tax Advice Should be Sought.....................................................................91
COMPETITION, MARKETS AND REGULATION ..........................................................................91
Competition................................................................................................91
Markets For Sale Of Production.............................................................................91
Regulation Of Production...................................................................................92
Natural Gas Prices.........................................................................................92
Oil and Liquid Hydrocarbon Price Controls..................................................................92
Possible Legislation.......................................................................................93
Regulation of the Environment..............................................................................93
LIABILITY OF GENERAL AND LIMITED PARTNERS.....................................................................93
General Partners...........................................................................................93
Limited Partners...........................................................................................94
SUMMARY OF PARTNERSHIP AGREEMENT AND DRILLING PROGRAM AGREEMENT...............................................95
Term.......................................................................................................95
Rights and Powers of Partners..............................................................................95
General and Limited Partners............................................................................95
Limited Partners........................................................................................96
General Partners........................................................................................96
Rights and Powers of the Managing Partner..................................................................97
Indemnification of the Managing Partner and its Affiliates.................................................97
Right of Presentment.......................................................................................98
Assignability of Interests.................................................................................98
Removal or Withdrawal......................................................................................99
Dissolution, Liquidation and Termination..................................................................100
Reconstitution of a Partnership...........................................................................101
Amendments................................................................................................102
Reports to Partners.......................................................................................102
Access to List of General and Limited Partners............................................................103
Power of Attorney.........................................................................................103
LEGAL OPINIONS...............................................................................................105
EXPERTS......................................................................................................105
WHERE YOU CAN FIND MORE INFORMATION .........................................................................105
Revenue recognition.................................................................................F1 - 3
EXHIBIT A: Form of Agreement of Partnership
EXHIBIT B: Form of Drilling Program Agreement
EXHIBIT C: Form of Special Subscription Instructions
EXHIBIT D: Form of Subscription Agreement
(iii)
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SUMMARY OF OFFERING
This summary highlights some information from this prospectus. It may
not contain all of the information that is important to you. To understand this
offering fully, you should read the entire prospectus carefully. For definitions
of key terms used in this prospectus, see "Definitions." FOR A DISCUSSION OF
MATTERS THAT SHOULD BE CONSIDERED IN EVALUATING AN INVESTMENT IN THE INTERESTS,
SEE "RISK FACTORS."
THE PARTNERSHIPS
We are offering to qualified investors an aggregate of up to 4,000
($4,000,000) limited partner interests and 16,000 ($16,000,000) general partner
interests in a series of two Delaware limited partnerships formed or to be
formed by us. We will sell these interests to investors for $1,000 each. The
minimum number of interests that we will offer for any one partnership is 1,000
interests that may be comprised of any combination of limited and general
partnership interests. The minimum subscription in any one partnership is five
interests ($5,000). The maximum number of interests that we will offer for any
one partnership is 10,000. Therefore, the minimum offering amount for any one
partnership will be $1,000,000 and the maximum offering amount for any one
partnership will be $10,000,000. A partnership will not commence operations or
have any material assets or liabilities prior to the termination of the
subscription period for interests in such partnership.
The offering of interests in Mewbourne Energy Partners 99-A, L.P.
commenced on August 10, 1999 and terminated on November 22, 1999. A total of 676
($676,000) limited partner interests and 5,051 ($5,051,000) general partner
interests in Mewbourne Energy Partners 99-A, L.P. were sold to a total of 29
persons and 208 persons, respectively.
The subscription period for interests in Mewbourne Energy Partners
00-A, L.P. will commence on the date of this prospectus and terminate on
November 1, 2000, unless we, as managing partner, in our sole discretion
accelerate or delay the offering termination date, provided that our ability to
delay the offering termination date is subject to our obligation to return the
purchase price for any interests not invested in a partnership within any period
required by state securities law.
A partnership will not be funded with less than $1,000,000 in capital
contributions from investors. If we have not received subscription funds of at
least $1,000,000 by the end of a partnership's subscription period, we will
promptly return all funds we have received for that partnership to subscribers.
Each partnership will terminate 50 years from the date of its formation.
We and our affiliates are eligible to subscribe for interests. However,
we may only purchase interests for investment purposes and not for resale or any
further public distribution. We currently intend to subscribe for as many
interests as may be necessary to assure that both partnerships receive the
minimum subscription amount of $1,000,000. The number of interests in the
partnerships that we may purchase is not subject to any specific maximum
limitations but instead depends upon the number of subscriptions we receive and
accept from non-affiliates.
INVESTMENT OBJECTIVES
Each partnership will participate in a drilling program consisting of
the acquisition, drilling and development of oil and gas prospects under a
drilling program agreement with us and our affiliate, Mewbourne Oil Company. The
primary investment objective of each partnership is to conduct oil and gas
drilling and development activities on prospects in an attempt to establish
long-life oil and gas reserves. In addition, the drilling program's structure is
intended to result in tax benefits, consisting principally of deductions for
intangible drilling costs, depletion, and depreciation. To the extent that the
operations of a partnership and the drilling program result in a net loss for a
taxable period, general partners will be able to claim their respective shares
of the deductions giving rise to such loss in the current year, but limited
partners will not be able to claim their shares of the deductions comprising
such loss in the current year except to the extent they have net passive income
from other sources. See "Tax Aspects." The drilling program agreement provides
that Mewbourne Oil Company, in its capacity as manager of the
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drilling program, will have the exclusive power and authority to act on behalf
of a partnership with respect to the management, control and administration of
the business and affairs of the drilling program and the oil and gas properties
subject to the drilling program agreement. See "Management."
Each drilling program is intended to be a partnership for income tax
purposes only. See "Tax Aspects -- Partnership Taxation -- Partnership
Classification." For all other purposes, each drilling program is intended to be
an agreement among us, the related partnership and Mewbourne Oil Company in its
capacity as manager of the drilling program. The participants in a drilling
program will be co-owners of undivided interests in the oil and gas properties
subject to that drilling program agreement. Each drilling program agreement sets
out the rights, duties, and obligations of the drilling program manager and the
other participants in the related drilling program.
PROPOSED ACTIVITIES
The primary objective of each partnership is to establish long-life oil
and gas reserves through the development of oil and gas prospects located in the
shelf and the shelf-slope regions of the Permian Basin, located in West Texas
and Southeastern New Mexico, and the Anadarko Basin, located in Western
Oklahoma, the Texas Panhandle and Southwest Kansas, by participating in a
drilling program formed and managed by Mewbourne Oil Company or its successor.
Although subject to change based on subsequent events and conditions, we
anticipate that each partnership will conduct oil and gas drilling and
development activities on prospects in the Permian and Anadarko Basins through a
drilling program. However, these prospects in the Permian and Anadarko Basins
have not yet been identified. In order to reduce the potential risks to the
participants, we anticipate that each partnership's activities through the
related drilling program will primarily focus upon activities relating to lower
risk development wells rather than higher risk exploratory wells. However, at
our discretion, a partnership may expend up to 20% of its capital contributions
in connection with activities relating to exploratory wells. See "Proposed
Activities." We may also determine that it is in the best interest of a
partnership to conduct activities in other geographic areas.
APPLICATION OF PROCEEDS
Interests in each partnership may be sold in an aggregate amount from
$1,000,000 to $10,000,000. There is no deduction from the proceeds realized from
the sale of interests to investors for organization and offering expenses, sales
commissions, and due diligence fees and, therefore, all of such sales proceeds
will be available to each partnership for the partnership's operations. The
managing partner under the terms of each drilling program agreement will pay all
organization and offering expenses, sales commissions, and due diligence fees.
See "Application of Proceeds" and "Participation in Costs and Revenues."
We estimate that of the total contributions made to each partnership's
drilling program approximately 8.4% will be expended for organization and
offering expenses, sales commissions and due diligence fees, approximately 15%
to 20% will be made in the form of lease acquisition costs of prospects,
approximately 12% to 16% will be expended for tangible costs, approximately 55%
to 60% will be expended for intangible drilling costs and the remainder will be
expended for other direct costs. These percentages are estimates only, and we
cannot assure that these percentages will be actually realized or that
variations in the percentages will not be significant to a partnership or its
drilling program.
INVESTMENT AS A LIMITED PARTNER OR GENERAL PARTNER
You have the option to invest in a partnership as a limited partner or
general partner. If you invest, the allocations of costs and revenues relating
to a partnership's drilling activities to you will be the same regardless of
whether you elect to become a limited partner or a general partner of a
partnership. However, if you elect to become a general partner you may
experience economic and tax consequences different from those you would
experience if you were to elect to become a limited partner due to differences
in the legal obligations and tax treatment of general partners and limited
partners. The tax treatment of income and deductions attributable to ownership
of interests by a limited partner will be more restrictive for many investors
than the treatment afforded income and deductions attributable to ownership of
interests by a general partner. We generally will receive the same tax benefits
and assume the same obligations as the general partners.
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Liability of General Partners. By law, each general partner is liable
for all of the obligations of a partnership. Furthermore, each partnership will
own working interests in oil and gas leases subject to some portion of the costs
of development, operation or maintenance. We, and likely others, will also own
similar working interests in these leases. Therefore, a general partner could be
liable for the obligations of all such joint working interest owners. The
subsequent conversion of a general partner interest into a limited partner
interest will have no effect on the converted general partner's liability as to
events that occurred prior to the conversion. However, the managing partner will
indemnify each general partner from any liability in excess of his share of a
partnership's undistributed assets. See "Risk Factors -- Particular Risks
Relating to the Interests -- Liability of Joint Working Interest Owners."
Liability of Limited Partners. Assuming that a limited partner does not
take part in the control of the business of a partnership, his liability under
Delaware law will be limited, generally to the amount of capital he has
contributed to the partnership. Under the laws of the states where we anticipate
the partnerships will conduct substantially all of their business, the liability
of limited partners will be governed by Delaware law. See "Liability of Investor
Partner--Limited Partners" and "Risk Factors -- Particular Risks Relating to the
Interests -- Liability of Limited Partners."
Under the terms of the partnership agreement, the managing partner may
not request or require additional capital contributions from general or limited
partners and, under the terms of the partnership agreement, general and limited
partners are not permitted to voluntarily make any additional capital
contributions to a partnership.
How to Subscribe. For instructions on how to subscribe for interests in
a partnership see "Terms of the Offering -- Subscription Procedure."
THE FOREGOING IS A VERY BRIEF SUMMARY OF MATTERS RELATING TO THE
OFFERING OF INTERESTS. THIS SUMMARY MUST BE CONSIDERED TOGETHER WITH INDEPENDENT
ADVICE AND A CAREFUL READING AND EXAMINATION OF THIS ENTIRE PROSPECTUS AND THE
ATTACHED EXHIBITS.
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RISK FACTORS
You should recognize that oil and gas drilling and exploration is a
high risk venture. Therefore, we recommend that you invest in a partnership only
if you are prepared to assume the substantial risks discussed below and
elsewhere in this prospectus. The nature of these risks requires persons who
purchase interests to be in a position:
o to hold such investment for a substantial number of years, and
o to absorb the possible loss of such investment.
PARTICULAR RISKS RELATING TO THE INTERESTS
Liability of Limited Partners. Each partnership will be governed by the
Delaware Revised Uniform Limited Partnership Act. Under Delaware law, as a
general rule, a limited partner's liability for the obligations of a partnership
is limited to such limited partner's capital contribution and such limited
partner's share of the partnership's assets. A limited partner of the
partnership will not otherwise be liable for the obligations of the partnership
unless, in addition to the exercise of his or her rights and powers as a limited
partner, such limited partner participates in the control of the business of a
partnership. In such case the limited partner is liable only to persons who
transact business with the partnership with actual knowledge of the limited
partner's participation in control. Accordingly, if a limited partner were to
take an action which was subsequently determined to constitute participating in
the control of the business of a partnership, such limited partner could become
liable for the partnership debts and obligations. See "Liability of Investor
Partners -- Limited Partners."
Liability of Investor General Partners. Under Delaware law, each
general partner in a partnership will be liable for all of the liabilities and
recourse obligations of the partnership. Furthermore, each partnership will own
working interests in oil and gas leases subject to some portion of the costs of
development, operation or maintenance. We, and likely others, will also own
similar working interests in these oil and gas leases. Therefore, a general
partner could be liable for the obligations of all such joint working interest
owners. The managing partner will indemnify each general partner from any
liability in excess of his share of a partnership's undistributed assets.
However, a general partner still could be subject to such liability if we should
become bankrupt or for any other reason we are unable to meet our financial
commitment to indemnify the general partners. This liability could obligate a
general partner to make additional payments to the partnership. The possible
amount of such a liability cannot be predicted. The subsequent conversion of a
general partner interest into a limited partner interest will have no effect on
the converted general partner's liability as to events that occurred prior to
the conversion. See"Liability of Investor Partners -- General Partners."
Liability of Joint Working Interest Owners. Under the drilling program
agreement, each drilling program participant, including the managing partner and
each partnership, will hold its working interest in oil and gas leases in its
own name and will be a joint working interest owner with the other drilling
program participants and also with third parties. It has not been clearly
established under the laws of some of the jurisdictions where a portion of each
drilling program's properties will be located whether a single joint working
interest owner is liable with respect to all obligations relating to the entire
jointly owned working interest. The operating agreements relating to drilling
program oil and gas leases will specify that the liabilities of joint working
interest owners will be limited to their individual joint working interest,
though we cannot assure that such a provision would be enforceable against a
third party. As a result it is possible that a general partner could be
determined liable for all obligations relating to the entire jointly owned
working interest.
Possibility of Reduction or Unavailability of Insurance Coverage of a
Partnership. It is possible that some or all of the insurance coverage which a
partnership has available may become unavailable or prohibitively expensive. If
the program manager and its affiliates cease to retain the coverage described
for any reason for a period of more than 20 days during the subscription period
for a partnership, the offering of interests in that partnership shall cease,
and subscribers for interests in any partnership in which investors have not
been admitted shall receive a refund of their subscription funds. The managing
partner will also promptly notify those investors of
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any material reduction in the insurance coverage of the drilling programs and
the partnerships. The managing partner shall give investors this notice as soon
as possible after it learns of such change and if possible at least 30 days in
advance of the change in insurance coverage. In addition, if a drilling program
or a partnership, after the admission of investors, has its insurance coverage
materially reduced for any reason, that partnership will halt all drilling
activity until such time as comparable replacement coverage is obtained. If a
partnership has its insurance coverage materially reduced after you invest, you
could be subject to a greater risk of loss of your investment since less
insurance would be available to protect your investment from casualty losses.
See "Proposed Activities -- Insurance."
Sole Reliance on Us for Management of a Partnership. Under the
partnership agreement, Mewbourne Development Corporation is designated as the
managing partner of each partnership and is given the exclusive authority to
manage and operate each partnership's business. As the managing partner, we will
have complete and total authority and broad discretion to determine the manner
in which all of the offering proceeds will be expended. Also, we are required to
devote only such time as is reasonably needed to the operations of the
partnerships. Accordingly, if you invest in a partnership you must rely solely
on us to make all decisions on behalf of each partnership. Investors will have
no role in the management of the business of either partnership. Therefore, each
partnership's success will depend, in part, upon the management we provide, our
ability, and the ability of Mewbourne Oil Company as manager of each drilling
program to:
o select and acquire oil and gas leases on which oil and gas wells
capable of producing oil and natural gas in commercial quantities may
be drilled,
o successfully drill and develop oil and gas well on the properties
selected, and
o market oil and natural gas produced from such oil and gas wells.
Sole Reliance on Our Financial Status. No financial information will be
provided to the investors concerning any investor who has elected to invest in a
partnership as a general partner. In no event, should investors rely on the
financial withwithal of investor general partners, including in the event we
should become bankrupt or are otherwise unable to meet our financial
commitments.
Prospects Not Yet Identified or Selected; No Opportunity to Evaluate
Prospects. Although we maintain an inventory of leasehold acreage covering
numerous prospects, we have not, as of the date of this prospectus, selected or
agreed to transfer from such owned inventory any particular oil and gas leases
to a partnership or related drilling program. The drilling program manager will
select all oil and gas leases that the partnerships and the related drilling
programs will acquire or drill. You will not have an opportunity to review those
oil and gas leases before investing in a partnership. You will also not have an
opportunity to participate in the selection of oil and gas leases after an
investment is made. We may during the course of this offering select, and cause
this prospectus to be amended or supplemented to describe, prospects designated
for acquisition by participants in a drilling program. If you subscribe for
interests prior to any such amendment or supplement you will not be permitted to
withdraw your subscription as a result of the selection of any such designated
prospect and you may not be notified of the selection of any such designated
prospect prior to funding of the partnership or partnerships in which you have
invested. See "Proposed Activities -- Acquisition of Leases."
Limited Ability to Spread Risk. A partnership could be formed with as
little as $1,000,000 in capital contributions from investors. To the extent that
the funds available to a partnership are limited, its ability to spread risks
over a large number of oil and gas wells and prospects will be reduced. The
number of oil and gas wells which can be drilled based on the minimum investment
amount cannot be determined because prospects have not been selected. However,
even if a drilling program is formed with substantially more than the minimum
required capital, investors must rely on us to diversify drilling activities of
the related partnership.
Ownership of Interests in a Partnership by Our Affiliates. We and our
affiliates are eligible to subscribe for interests. However, any interests we or
our affiliates purchase must be purchased for investment purposes only and not
for the purpose of resale or any further public distribution. As the initial
managing partner, we currently intend
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to subscribe for such number of interests as may be necessary for each
partnership in which interests are being offered to receive the minimum
subscription number of 1,000 interests. The number of interests in a partnership
that we and/or our affiliates may purchase is not subject to any specific
maximum limitations but instead depends upon the number of subscriptions for
interests received and accepted from non-affiliates. Therefore, there are no
limitations upon the number of interests that we or our affiliates may purchase.
Interests we or our affiliates own will have voting rights under the partnership
agreement. However, during the time period that we or our affiliate serve as the
managing partner of a partnership, any interests we or our affiliates own, which
in the aggregate represent more than 20% of the total interests held by the
general and limited partners in the partnership shall not have any voting rights
under the partnership agreement and shall not be counted for voting purposes or
for purposes of determining a quorum. In addition, none of the interests owned
by us or our affiliates shall be counted for voting purposes or for purposes of
determining a quorum or have any voting rights concerning the removal of us as
managing partner or any transaction between that partnership and us or our
affiliates. Notwithstanding the voting limitations imposed upon interests owned
by us or our affiliates, to the extent that we or our affiliates acquire
interests in a partnership, such ownership will dilute the voting power of the
other investors in that partnership.
Additional Partnership Financing May Become Necessary Due to Unforeseen
Circumstances. We anticipate that the net proceeds from the sale of interests in
a particular partnership will be sufficient to finance that partnership's share
of the related drilling program's costs of:
o drilling and completing oil and gas wells, and
o providing necessary production equipment and facilities to
service such oil and gas wells and plugging and abandoning
non-productive oil and gas wells.
However, due to unforeseen circumstances, it could become necessary to finance
the costs of additional partnership operations through partnership borrowings,
utilization of partnership revenues obtained from production or other methods of
financing. These additional operations may include the acquisition of additional
oil and gas leases and the drilling, completing and equipping of additional
wells to further develop drilling program prospects. Each partnership agreement
provides that outstanding partnership borrowings may not at any time exceed 20%
of the aggregate capital contributions of the general and limited partners.
Furthermore, a partnership may borrow funds only if the lender agrees that it
will have no recourse against individual general partners. If the
above-described method of financing should prove insufficient to maintain the
desired level of development operations for the drilling program, such
operations could be continued through farmout arrangements with third parties,
including the managing partner and/or its affiliates. These farmouts could
result in the drilling program giving up a substantial interest in any oil and
gas revenues so developed.
Uncertainty of Partnership Cash Distributions. No distributions will be
made from a partnership to the general or limited partners of that partnership
until that partnership has funds which the managing partner determines are not
needed for the operation of the partnership and the drilling program.
Accordingly, we cannot assure that any distributions from a partnership will be
made to its general and limited partners. Distributions will depend primarily on
a partnership's net cash receipts from oil and gas operations. Moreover,
distributions could be delayed to repay the principal and interest on
partnership borrowings, if any, or to fund partnership costs. partnership income
will be taxable to the general and limited partners in the year earned, even if
cash is not distributed.
Conflicts of Interest of Managing Partner. Investors will not be
involved in the day-to-day operations of the partnerships. Accordingly, if you
invest in a partnership, you must rely on our judgment in such matters. Inherent
with the exercise of our judgment, we will be faced with conflicts of interest,
including:
o We will participate in the drilling programs in our individual
capacity. As a result, actions taken by a partnership may be
more beneficial to us than the partnership,
o We or our affiliates may participate in oil and gas activities
on behalf of other programs that we sponsor, will sponsor or
are for our account. We owe a duty of good faith to each of
the partnerships which we manage and it is possible that
actions taken with regard to other partnerships may not be
advantageous to a partnership.
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o We and/or our affiliates may provide services to a
partnership. We and/or our affiliates will be compensated for
these services at rates competitive with the rates charged by
unaffiliated persons for similar services.
o If we or our affiliates' own interests in a partnership this
ownership may dilute the voting power of the other general and
limited partners in that partnership.
o The oil and gas leases that may be contributed to a
partnership may be adjacent to acreage or oil and gas leases
which we or our affiliates hold or will hold. While the
drilling program will not drill any well for the purpose of
proving or disproving the existence of oil or gas on any
adjacent acreage, such drilling activities may incidentally
develop information valuable to us or our affiliates in
evaluating our nearby acreage at no cost to us. Accordingly, a
conflict of interest will exist between our interests and the
interest of a partnership in selecting the location and type
of operations which the drilling program will conduct on
drilling program oil and gas leases.
We will attempt, in good faith, to resolve all conflicts of interest in a fair
and equitable manner with respect to all persons affected by those conflicts of
interest. However, we cannot assure that transactions between a partnership and
its affiliates will be on terms as favorable as could have been negotiated with
unaffiliated third parties. You should be aware that we have not formally
adopted any procedures or criteria to avoid or to resolve any conflicts of
interest that may arise between us and a partnership. You are urged to review
the discussion under "Conflicts of Interest" for a more complete description of
possible conflicts of interests.
Inside Board of Directors and Other Family Relationships of Managing
Partner and Program Director. The Board of Directors of both the managing
partner and the program manager are comprised entirely of employees and family
members of Mr. Mewbourne. Therefore, the activities of the managing partner and
the program manager are not subject to the review and scrutiny of an independent
Board of Directors.
Limitations on the Fiduciary Obligations of the Managing Partner and
the Managing Partner's Responsibility to Determine the Application of the
Limitations. The partnership agreement contains provisions which modify what
would otherwise be the applicable Delaware law relating to the fiduciary
standards of the managing partner to the general and limited partners. The
fiduciary standards in the partnership agreement could be less advantageous to
the general and limited partners and more advantageous to the managing partner
than the corresponding fiduciary standards otherwise applicable under Delaware
law, specifically:
o we and our affiliates may be indemnified and held harmless by
a partnership,
o we are required to devote only so much of its time as is
necessary to manage the affairs of a partnership'
o we and our affiliates may conduct business with a partnership
in a capacity other than as a manager of the partnership,
o we and/or our affiliates may pursue business opportunities
that are consistent with a partnership's investment objectives
for their own account if we determine that such opportunity
cannot be pursued by the partnership either because of
insufficient funds or because it is not appropriate for the
partnership under the existing circumstances, and
o we may manage multiple programs simultaneously.
In addition, the partnership agreement limits the liability of us or
our affiliates to a partnership or to general and limited partners for acts or
omissions if we determine in good faith, as of the time of the conduct or
omission, that the course of conduct or omission was in the best interest of
that partnership and that such conduct or omission did not constitute negligence
or misconduct.
Your purchase of an interest in a partnership may be deemed as consent
to the limitations upon the fiduciary standards set forth in the partnership
agreement. As a result of these provisions in the partnership agreement, the
general and limited partners may find it more difficult to hold us responsible
for not acting in the best interests of a partnership and its general and
limited partners than if the fiduciary standards of the otherwise applicable
Delaware law governed the situation.
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Partnership's Joint Activities With Others. We anticipate that the
participants in the drilling programs, including the related partnerships, will
not own the full working interest in most prospects to be explored and developed
under the drilling program agreement. It is likely that a third party or parties
will own a partial working interest in a prospect to be developed under the
drilling program agreement. These third parties could be either our affiliates
or unrelated to us and could also include Mr. Mewbourne. While Mewbourne Oil
Company, on behalf of each drilling program, would participate in decisions
affecting the development of such prospects, decisions with respect to
development activities might be controlled or affected by the other owners of
working interests in such prospects. Furthermore, a partnership could be held
liable for the joint activity obligations of such other working interest owners,
and this liability could in turn result in individual liability for the general
partners in that partnership. See "-- Particular Risks Relating to the Interests
- -- Liability of Joint Working Interest Owners."
Lack of Liquidity for Investors. We anticipate that there will not be
any market for resale of the interests. Although the partnership agreement
permits the assignment of interests by general and limited partners, transfers
of interests are subject to restrictions. As one example, an assignee of an
interest may not become a substituted general or limited partner without our
consent. Accordingly, if you purchase an interest you should be prepared to bear
the investment risks attendant upon your investment for an indefinite period of
time. See "Summary of Partnership Agreement and Drilling Program Agreement --
Assignability of Interests" for a description of transfer restrictions.
General and limited partners will not have the right to withdraw any
capital from a partnership or to receive the return of all or any portion of
their capital contributions, except out of distributions of operating revenues,
upon a sale or other disposition of that partnership's property or the
dissolution and liquidation of that partnership. Although general and limited
partners may under certain circumstances require us, or an affiliate that we
have designated, to purchase their interest in whole but not in part, this
obligation is limited and does not assure the liquidity of an investor's
investment. See " Terms of the Offering -- Right of Presentment."
Indemnification of Managing Partner and its Affiliates. The partnership
agreement provides for indemnification of us, our affiliates and the officers
and directors of such persons against claims arising from conduct on behalf of a
partnership or the related drilling program. In addition, the drilling program
agreement provides for indemnification of Mewbourne Oil Company, its affiliates,
and the officers and directors of such persons against claims arising from
conduct on behalf of the related drilling program. In the event of any such
indemnification for losses, liabilities or expenses arising from or out of an
alleged violation of federal or state securities laws, a court must approve the
indemnification. In all other instances of indemnification, we will decide
whether or not indemnification is appropriate under the partnership agreement or
drilling program agreement. Therefore, if you invest, in such situations you
must rely upon our integrity to cause a partnership to indemnify us and our
affiliates only when such indemnification is justified under the partnership
agreement or drilling program agreement. You should also bear in mind that in
any situation involving indemnification, a partnership's funds could be applied
to the indemnification of us and our affiliates rather than to make
distributions to the general and limited partners. See "Summary of Partnership
Agreement and Drilling Program Agreement -- Indemnification of the Managing
Partner and its Affiliates.
Investor's Lack of Substantial Voting Rights. In order to preserve the
limited liability of the limited partners of the partnerships, the limited
partners may not take part in the day to day operations of a partnership.
Although those investors who elect to invest as general partners will not
initially be limited partners of a partnership, we are presuming that the vast
majority, if not all, of the general partner interests will be converted into
limited partner interests upon completion of the partnership's drilling
activities. In order to preserve the limited liability of the limited partners,
limited partners are not permitted to take actions which generally may be taken
by stockholders of public corporations, such as annual votes to approve
important matters. Because limited partners are not permitted to take part in
the day to day operations of a partnership, limited partnerships, such as the
partnerships, do not generally hold annual meetings such as those at which
stockholders may express their views and confront management directly. As a
result of the control of the day to day operations of a partnership is vested
exclusively in us, and you must rely on us to fulfill our fiduciary duties to
you and the other partners and to maximize the partnership's economic
performance.
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Investor's Lack of Appraisal Rights. Unlike most modern corporation
laws and the solid body of judicial case law which provides most corporate
stockholders with appraisal rights to have their shares of stock redeemed by the
corporation in certain instances, limited partnership acts generally provide no
such rights. Although the partnership agreement does provide general and limited
partners with limited appraisal rights in the case of mergers and similar
events, an investor may not have appraisal rights in as many situations as would
some corporate stockholders. There is no extensive judicial case law
interpreting and upholding the appraisal rights of limited partners. See
"Proposed Activities --The Managing Partner's Policy Regarding Roll-Up
Transactions" for a description of the limited appraisal rights provided to
general and limited partners.
Limited Ability to Remove Managing Partner and Difficulty in Finding a
Successor Managing Partner. We may be removed from our position as the managing
partner and/or Mewbourne Oil Company may be removed from its position as the
drilling program manager only by the affirmative vote of investors holding at
least 50% of the then outstanding general and limited interests of such
partnership. The general and limited partners in certain circumstances must, in
order to continue the partnership, elect a successor to the removed managing
partner if the removal of the managing partner causes a dissolution of that
partnership. In the event the drilling program manager is removed, the related
partnership must elect a successor to the removed drilling program manager.
There is a risk that the general and limited partners could not find a new
managing partner or drilling program manager if we or Mewbourne Oil Company were
to be removed from such positions.
Withdrawal of Partners. Under the partnership agreement, each general
partner will agree that he will not voluntarily withdraw from a partnership. We
agree that we will not voluntarily withdraw from a partnership prior to the
later to occur of:
o completion of the partnership's primary drilling activities
under the related drilling program, and
o the fifth anniversary of the date that general and limited
partners were admitted to the partnership.
In order to exercise its right of withdrawal, we must give the general
and limited partners at least 120 days' advance written notice. A general
partner who withdraws in violation of this agreement will be obligated to
reimburse the partnership and the other partners for any expenses associated
with such withdrawal. We expect that such expenses may be substantial and could
exceed the amount of the withdrawing general partner's original investment in
the partnership. Furthermore, a withdrawing general partner will no longer be
entitled to receive any distributions nor shall such general partner have any
rights as a partner under the partnership agreement.
Dissolution of a Partnership and Termination of the Drilling Program. A
partnership will be dissolved and terminated upon the occurrence of any of the
events listed under "Summary of Partnership Agreement and Drilling Program
Agreement -- Dissolution, Liquidation and Termination." These events include:
o the expiration of that partnership's term or
o the vote or consent in writing at any time by a majority in
interest of the general and limited partners.
However, a partnership could also be dissolved and both it and the related
drilling program terminated as a result of events which do not include the
passage of time or the consent of the general and limited partners. These events
include our bankruptcy, insolvency, dissolution, or withdrawal from the
partnership. The general and limited partners have the right to reconstitute a
partnership under such circumstances and, in so doing, avoid termination of that
partnership. However, there is no certainty that the general and limited
partners could find a new managing partner to replace us in such circumstances.
We currently have no intention of withdrawing as the managing partner of a
partnership.
Ability of the Managing Partner to Cause Dissolution of a Partnership
and the Related Drilling Program. The partnership agreement and applicable law
provide our withdrawal from a partnership, directly or as a result of
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bankruptcy, dissolution or similar event, will cause dissolution of that
partnership. We have undertaken not to withdraw as the managing partner of a
partnership prior to the later to occur of
o completion of that partnership's primary drilling activities
under the related drilling program, and
o the fifth anniversary of the date that general and limited
partners were admitted to that partnership.
However, we have the power under applicable law to withdraw from a partnership
in violation of the partnership agreement. We currently do not intend to
withdraw from a partnership. The partners of each partnership are given the
right under the partnership agreement to reconstitute a partnership upon our
withdrawal, but there is an additional risk in such event that the partners of a
partnership could not find a successor managing partner.
Unauthorized Acts of General Partners Could Be Binding Against the
Partnership. Under Delaware law, the act of a general partner of a partnership
apparently carrying on the business of the partnership binds the partnership,
unless the general partner in fact has no authority to act for the partnership
and the person with whom the partner is dealing has knowledge in good faith of
the fact that such general partner has no such authority. While there is a risk
that a general partner might bind a partnership by his acts, we believe that the
managing partner will have such exclusive control over the conduct of the
business of the partnerships that it is unlikely that a third party, in the
absence of bad faith, would deal with a general partner in connection with a
partnership's business. The participation by a general partner in the management
and control of a partnership's business is expressly prohibited by the
partnership agreement, and a violation of such prohibition would give rise to a
cause of action by the partnership against such general partner. Nevertheless,
there is always the possibility that a general partner could attempt to take
unauthorized actions on behalf of a partnership, and if a court were to hold
that such actions were binding against the partnership such unauthorized actions
could be contrary to the best interests of that partnership and could adversely
impact such partnership.
GENERAL RISKS RELATING TO OIL AND NATURAL GAS OPERATIONS
Loss of Investment Due to Speculative Nature of Oil and Gas Activities.
Development of oil and gas properties is not an exact science and involves a
high degree of risk which could result in a loss of a partner's investment or
personal liability on the part of a general partner. Under the drilling program
agreement, the activities of each partnership will focus upon the acquisition of
oil and gas leases, the drilling of development wells, the development of
prospects, and the production and operation of the resulting properties. In
addition to development wells, at our discretion, up to 20% of a partnership's
capital contributions may be expended in connection with activities relating to
exploratory wells. All drilling activities involve a high degree of risk with
exploratory wells presenting a higher degree of risk than development wells. We
cannot assure that the objective formation(s) will be encountered or that any or
sufficient oil or gas production will be obtained through drilling program
activities, or if production is obtained, that such production will be sold at
sufficient prices to enable an investor to recoup his investment in a
partnership. During the drilling and completion of wells, a drilling program
could encounter hazards such as unusual or unexpected formations, pressures or
other conditions, blow-outs, fires, failure of equipment, downhole collapses,
and other hazards, whether similar or dissimilar to those enumerated. Although a
partnership will maintain the insurance coverage described under "Proposed
Activities -- Insurance," the drilling program may suffer losses due to hazards
against which it cannot insure or against which it may elect not to insure. Such
liabilities could result in personal liability for a general partner.
The Partnerships and the General Partners Could be Liable for
Environmental Hazards. There are numerous natural hazards involved in the
drilling of wells, including unexpected or unusual formations, pressures,
blowouts, and accidental leakage involving possible damage to property and third
parties. Such hazards may cause substantial liabilities to third parties or
governmental entities. Although we anticipate that customary insurance will be
obtained, a partnership may be subject to liability for pollution and other
damages due to hazards which cannot be insured against or will not be insured
against due to prohibitive premium costs or for other reasons. Liabilities to
third parties or governmental entities for pollution could reduce funds
available for distributions and for drilling operations, result in the loss of
partnership property, or result in the personal liability of the general
partners if the
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liability exceeded insurance proceeds, a partnership's assets, and the managing
partner's ability to indemnify such general partners.
Return on Investment is Dependent on Future Prices, Supply and Demand
for Oil and Gas. The revenues generated from the activities of each partnership
and the return on the investments made by the partner's will be highly dependent
upon the future prices and demand for oil and gas which can be volatile. The
high and low average monthly posted price for crude oil received by the drilling
program manager during 1999 was approximately $25.26 per barrel and $9.30 per
barrel, respectively. The high and low monthly average price received by the
drilling program manager for gas produced and sold during 1999 was approximately
$2.90 per mmbtu and $1.53 per mmbtu, respectively. Factors which may affect
prices and demand include the world-wide supply of oil and gas, the price of
foreign imports, the levels of consumer demand, price and availability of
alternative fuels and changes in existing and proposed federal regulation and
taxation. Also, gas prices remain somewhat seasonal in nature and, for this
reason, it is particularly difficult to estimate accurately future prices of
gas, and any assumptions concerning future prices may prove to be incorrect.
The United States average daily production of oil declined from 9.0
million barrels in 1985 to approximately 6.0 million barrels in 1999. The
reduced production level is in part the result of decreased drilling activity in
the United States. Drilling activity is measured by the United States rig count
which declined from 1,003 at the end of 1997 to 771 at the end of 1999. Another
factor contributing to the reduction of United States oil production is the
plugging and abandoning of wells which are uneconomical due to the significant
decrease in the price of oil.
The United States import levels for oil have increased significantly
since 1985. In 1985, imports of foreign oil represented 27% of the United
States' demand. During the year 1999, imports averaged approximately 58% of the
United States' consumption.
Government Regulation of a Partnership's Activities. The oil and gas
business is subject to extensive governmental regulation under which, among
other things, rates of production from oil and gas wells may be regulated.
Governmental regulation also may affect the market for a partnership's
production. Governmental regulations relating to environmental matters could
also affect a partnership's operations. We cannot predict the nature and extent
of various regulations, the nature of other political developments and their
overall effect upon a partnership and the related drilling program.
TAX RISKS
General. We have not requested, and we will not request, a ruling from
the IRS regarding the tax consequences of investing in interests. Based on our
representations and various assumptions and qualifications, our counsel has
rendered an opinion that the material federal income tax benefits of an
investment in interests, in the aggregate, more likely than not will be realized
in substantial part by a partner who is an individual United States citizen and
who acquires his interests for profit, provided that an investor who acquires
limited partner interests either is not subject to the passive activity loss
limitations of Section 469 of the Internal Revenue Code or has sufficient
passive income against which he can deduct his share of any partnership
deductions and losses. See "Tax Aspects -- Opinion of Counsel."
Partnership Classification for Tax Purposes; No IRS Ruling Sought. In
order for income and deductions to be passed through to the general and limited
partners, a partnership and the related drilling program must be classified as
partnerships for federal income tax purposes. If a partnership or the related
drilling program were taxed as a corporation for federal income tax purposes,
the tax consequences resulting from the ownership of interests would be
adversely affected and any anticipated federal income tax benefits would be
reduced or eliminated. Based on our representations and various assumptions and
qualifications, our counsel is of the opinion that, at the time of formation,
each partnership and each related drilling program will be treated as a
partnership for federal income tax purposes and that neither partnership will be
treated as a corporation under the "publicly traded partnership" rules of
Section 7704 of the Internal Revenue Code. We cannot assure, however, that
future legislative, judicial or
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administrative action will not affect the classification of a partnership or a
drilling program for federal income tax purposes. See "Tax Aspects --
Partnership Taxation -- Partnership Classification."
Allocations. The partnership agreement and the drilling program
agreement contain provisions that allocate federal income tax consequences of a
drilling program's activities among us and the general and limited partners. If
such allocation provisions were not recognized for federal income tax purposes:
o a portion of the federal income tax deductions allocated to
and claimed by the general and limited partners, including
deductions for intangible drilling costs, could be reallocated
to us. This reallocation could occur notwithstanding the fact
that such general and limited partners had been charged with
the expenditures giving rise to such deductions, and
o a portion of the taxable income allocated to us could be taxed
to the general and limited partners. This allocation could
occur notwithstanding the fact that the revenues giving rise
to such taxable income had been credited to us.
Based on our representations and various assumptions and qualifications, our
counsel is of the opinion that, except as noted below, the allocation of income,
gains, losses, and deductions between us and the general and limited partners
under the partnership agreement and between us and a partnership under the
drilling program agreement will be recognized for federal income tax purposes.
Our counsel's opinion is not binding on the IRS, however, and we cannot assure
that the IRS will not challenge such allocations.
Passive Activity Limitations. A limited partner's interest in a
partnership will be treated as a "passive activity," and any tax losses derived
by a limited partner from a partnership will be allowable only to the extent of
such limited partner's "passive income." Disallowed passive losses in any year
can be carried forward indefinitely and used to offset future passive income or
can be deducted in full when the limited partner disposes of his entire interest
in the partnership to an unrelated person in a fully taxable transaction.
A taxpayer's interest in an oil or gas well drilled or operated under a
working interest does not constitute a passive activity so long as the taxpayer
owns the working interest directly or through an entity that does not limit the
taxpayer's liability with respect to such drilling or operation. Based on our
representations and various assumptions and qualifications, our counsel is of
the opinion that the passive activity loss limitations of Section 469 of the
Internal Revenue Code should not apply to general partners in a partnership,
prior to any conversion of a general partner interest to a limited partner
interest, to the extent that a partnership drills or operates wells under
working interests. Consequently, each general partner should be entitled to
deduct currently his share of intangible drilling and development costs and
other deductible expenses allocable to the drilling or operation of wells under
working interests without regard to the passive activity loss limitations.
However, a general partner's ability to take deductions will be subject to basis
and "at risk" limitations. The exception for working interests would not be
applicable to any operations of a partnership other than the drilling and
operation of wells under working interests. Therefore, if a partnership acquires
an interest or participates in other activities, such activities will be treated
as passive activities to the general partners and any losses derived by them
with respect to such activities will be passive losses allowable only to the
extent of their passive income. In addition, the exception for working interests
will not apply from and after a conversion of a general partner interest to a
limited partner interest. See "Tax Aspects -- Special Features of Oil and Gas
Taxation -- Passive Activity Loss Limitations."
The treatment of a partnership as a "publicly traded partnership" for
purposes of applying the passive activity loss limitations would even more
severely restrict or eliminate a limited partner's ability to use any
partnership losses to offset income from other sources. Based on our
representations and various assumptions and qualifications, our counsel is of
the opinion that neither partnership will be treated as a publicly traded
partnership for purposes of the application of the passive activity loss
limitations of Section 469 of the Internal Revenue Code. Our counsel's opinion
is not binding on the IRS, however, and we cannot assure that the IRS will not
assert that a partnership is a publicly traded partnership for purposes of
applying the passive activity loss limitations.
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Considerations for Tax-Exempt Investors. Entities otherwise generally
exempt from federal income tax, such as IRAs, Keogh Plans, qualified employee
benefit plans, and charitable organizations, are taxed on "unrelated business
taxable income" in excess of $1,000 in any particular year. Substantially all
the income from a partnership's operations will constitute "unrelated business
taxable income" and may give rise to tax liability to an otherwise tax-exempt
investor which is a limited partner or a general partner. Such investor may be
required to file a tax return even if the investor does not realize net taxable
income from a partnership or taxable income exceeding $1,000 in a year.
Tax Shelter Registration. Although an investment in a partnership may
generate tax benefits, a partnership should not be considered a "tax shelter" as
that term is commonly understood. Nevertheless, because of the expansive
definition of the term "tax shelter" under applicable Treasury Regulations, we
will apply to the IRS for a "tax shelter" registration number with respect to
each partnership. We will furnish the registration number to each partner. Each
partner must include the registration number on his individual tax return and
must furnish the number and certain other information to any transferee of his
interests. We will also maintain and make available to the IRS on request a list
of the general and limited partners in each partnership. There may be a greater
likelihood that partners in a partnership will be audited by the Internal
Revenue Service because the partnership has been registered as a "tax shelter."
Current Tax Deductions. We will use reasonable efforts to expend or
contract for the expenditure of the capital contributions of each partnership in
the year such contributions are received. However, some of the expenses may be
incurred prior to the actual drilling of the oil and gas wells. We cannot assure
that any intangible drilling costs incurred in a year prior to the year of the
actual drilling of the oil and gas wells will be deductible in the year
incurred. In particular, a partnership might not expend or contract for the
expenditure of a substantial portion of its capital contribution in the year in
which general and limited partners are admitted to a partnership, in which event
no substantial partnership tax deductions would be available in that year. We
have sponsored a series of ten public limited partnerships similar to the
partnerships being offered by this prospectus since December 1992 and, based on
the historic results of these previous limited partnerships, we anticipate that
no more than 50% of the total intangible drilling costs incurred by a
partnership will be incurred and deductible by investors in that partnership in
the year they are admitted as general or limited partners to such partnership.
See "Tax Aspects -- Anticipated Federal Income Tax Deductions."
Conversion of General Partner Interests. We anticipate that the general
partner interests in a partnership will be converted to limited partner
interests following the completion of the partnership's drilling activities. We
anticipate a partnership will complete drilling activities within approximately
8 to 15 months after the funding of the partnership. The tax consequences of
such a conversion will depend upon the law in existence at the time of
conversion and upon the results of that partnership's operations prior to that
time. Such consequences may be adverse if the conversion is deemed a
"constructive termination" of the partnership for federal income tax purposes or
may be adverse under the passive loss rules as a result of a partner's
particular circumstances. If we determine that the conversion of the general
partner interests in a partnership to limited partner interests will have an
adverse effect on the general partners or the partnership, due to adverse tax
consequences or other reasons, we may elect not to convert those interests.
Accordingly, we cannot assure that any general partner interests will be
converted to limited partner interests or when any such conversion will occur.
Tax Liabilities in Excess of Cash Distributions. A partner must report
and pay income tax on his share of partnership income, regardless of whether
such income is retained and used for debt service, working capital, or other
reasons, any of which uses may not give rise to deductions for federal income
tax purposes. The receipt of cash distributions by the general and limited
partners may be delayed due to various factors, such as the use of revenues to
finance permitted activities. To the extent that the general and limited
partners are credited with net income from a partnership, an income tax
liability will be incurred even though the general and limited partners may not
yet have received any cash distributions from the partnership. The timing and
amount of cash distributions will be determined by us in our complete
discretion. If you invest in a partnership, you will be required to report your
share of any partnership income on your federal, state and local tax returns and
you will be responsible for the payment of taxes attributable to such income. In
any year, your resulting tax liability may exceed the amount of cash distributed
to you by a partnership.
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Risks of Borrowings. We are authorized to cause a partnership to obtain
additional loans from banks or other financial sources, or from us or our
affiliates, provided that the total amount of such loans may not in the
aggregate exceed 20% of the capital contributions to the partnership. A
partner's share of revenue applied to the repayment of loans, will be included
in his taxable income. Although such income may be offset in part by deductions
for depletion, cost recovery, depreciation, and intangible drilling costs, such
loans could cause a partner to become subject to an income tax liability in
excess of the amount of cash distributions he receives from the partnership.
Percentage Depletion. Percentage depletion deductions are tax
deductions calculated based upon a percentage of gross income from the property,
but are limited to 100% of the total taxable income of the partner from the
property for each taxable year, and are only available to limited partners
qualifying as independent producers. Because depletion deductions must be
computed separately by each partner and not at the partnership level, the
availability of percentage depletion will depend in part upon a partner's
individual circumstances. Therefore, each individual investor may not be
eligible to claim percentage depletion deductions. See "Tax Aspects -- Special
Features of Oil and Gas Taxation -- Depletion."
Farmouts and Backin Interests. If a partnership acquires working
interests in oil and gas leases under the terms of a farmout agreement, a
portion of the value of such working interests may have to be reported as
taxable income. In addition, the ability of a partnership to deduct all
intangible drilling costs paid by it with respect to oil and gas leases burdened
by a backin working interest may be limited. A backin working interest is a
right held by another party to become a working interest owner in the oil and
gas lease on payout of the initial well on the oil and gas lease. See "Tax
Aspects -- Special Features of Oil and Gas Taxation -- Farmouts and Backin
Interests."
Recapture. Certain deductions for intangible drilling costs, depletion,
and depreciation must be recaptured as ordinary income on disposition of
property by a partnership or on disposition of interests by a partner. If a
partnership disposes of property or a partner transfers an interest, the
partnership, and the partners may recognize ordinary income (instead of capital
gain) to the extent such deductions for intangible drilling costs, depletion and
depreciation must be recaptured. See "Tax Aspects -- Special Features of Oil and
Gas Taxation -- Intangible Drilling and Development Costs," "-- Depletion" and
"-- Depreciation."
Audits. The IRS may audit the tax returns of the partnership you invest
in or its related drilling program, in which case an audit of your individual
tax returns also may result. If such audits occur, tax adjustments may be made,
including adjustments to items on your returns unrelated to the partnership.
Furthermore, any settlement or judicial determination of the partnership's or
the drilling program's income may be binding on you. This is the case even
though you may not have participated directly in the settlement proceedings or
litigation. See "Tax Aspects -- Partnership Taxation -- Elections and Returns."
Changes in Federal Income Tax Laws. Significant and fundamental changes
in the nation's federal income tax laws have been made in recent years and
additional changes are likely. Any such change may affect the partnerships and
the general and limited partners. Moreover, judicial decisions, regulations or
administrative pronouncements could unfavorably affect the tax consequences of
an investment in a partnership. See "Tax Aspects -- Other Tax Consequences --
Changes in Federal Income Tax Laws."
Significance of Tax Aspects. These interests are being offered to
parties who may avail themselves of the benefits presently allowed oil and gas
activities under federal income tax laws. We cannot assure that:
o money invested in a partnership will be recovered,
o any capital contributions to a partnership will be expended
and result in any tax deductions in the year such
contributions are received by a partnership,
o federal income tax laws or the present interpretation of those
laws will not be changed, or that
o any position taken by a partnership or a drilling program on
its federal income tax returns will not be challenged by the
IRS.
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In addition, federal income tax provisions may:
o limit deductions,
o trigger or increase a partner's liability for the alternative
minimum tax on tax preference items,
o increase tax liability on the disposition of interests,
o or otherwise increase the federal income tax liability of a
partner.
Notwithstanding enactment of additional legislation or interpretations of
legislation which might require different treatment from the discussion under
"Tax Aspects," a partnership is authorized to expend the proceeds from the sale
of interests and to conduct its business and operations as described in this
prospectus. Each item of partnership income, gain, loss, or deduction will be
shared or borne financially in the manner specified in this prospectus. It is
suggested that you obtain professional guidance from your tax advisor in
evaluating the tax risks involved in investing in a partnership.
FORWARD LOOKING STATEMENTS
Forward-looking statements are inherently uncertain some statements
under the captions "Summary of Offering," "Risk Factors," "Application of
Proceeds," and elsewhere in this prospectus are forward-looking statements.
These forward-looking statements include, but are not limited to, statements
about our industry, plans, objectives, expectations, intentions and assumptions
and other statements contained in the prospectus that are not historical facts.
When used in this prospectus, the words "expect," "anticipate," "intend,"
"plan," "believe," "seek," "estimate" and similar expressions are generally
intended to identify forward-looking statements. Because these forward-looking
statements involve risks and uncertainties, including those described in this
"Risk Factors" section, actual results may differ materially from those
expressed or implied by these forward-looking statements. We do not intend to
update or revise any forward-looking statements, whether as a result of new
information, future events or otherwise. Market data and forecasts used in this
prospectus have been obtained from independent industry sources. Although we
believe these sources are reliable, we do not guarantee the accuracy and
completeness of historical data obtained from these sources and we have not
independently verified these data. Forecasts and other forward-looking
information obtained from these sources are subject to the same qualifications
and the additional uncertainties accompanying any estimates of future market
size.
APPLICATION OF PROCEEDS
Interests in each partnership may be sold in an aggregate amount from
$1,000,000 to $10,000,000. There is no deduction from the proceeds realized from
the sale of interests to investors for organization and offering expenses, sales
commissions, and due diligence fees and, therefore, all of such sales proceeds
will be available to each partnership for the partnership's operations. The
managing partner under the terms of each drilling program agreement will pay all
organization and offering expenses, sales commissions, and due diligence fees.
See "Application of Proceeds" and "Participation in Costs and Revenues."
A partnership may receive capital contributions by the investor
partners ranging from a minimum of $1,000,000 to a maximum of $10,000,000.
Regardless of the amount of capital contributions received, each partnership
will have sufficient capital to engage in the proposed activities as set forth
under "Proposed Activities." However, to the extent that a partnership receives
the minimum capital contributions from the investor partners, the ability of
that partnership to participate in a large number of program wells and prospects
will be reduced, and therefore, the partnership may have a concentration of
risk. See "Risk Factors -- Particular Risks Relating to the Interests --
Concentration of Investment Risks." It is not anticipated that the liquidity of
a partnership will depend upon the amount of capital contributions received from
the investor partners, because as set forth below, all of the capital
contributions are to be expended and none of such funds will be retained for
liquidity purposes. A partnership's liquidity is dependent upon the amount of
revenues, if any, which are realized as a result of the partnership activities.
See "Proposed Activities -- Partnership Distributions."
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We do not anticipate that we will make any capital contributions
directly to a partnership, but rather we will make our capital contributions
directly to the drilling program in which the partnership is a participant. We
will contribute to each drilling program the oil and gas leases upon which the
drilling program will conduct its operations. Our contribution of oil and gas
leases to each drilling program will be credited to the drilling program at the
lease acquisition costs of the oil and gas leases contributed or at fair market
value if the lease acquisition costs is materially more than fair market value.
The aggregate amount of contributions we will make to the related
drilling program as a participant, in respect of organization and offering
expenses, sale commissions, due diligence fees and oil and gas leases, must
equal at least 42% of the capital contributions initially made by investor
partners to the related partnership. In the event that our aggregate
contributions to the related drilling program in respect of organizational and
offering expenses, sale commissions, due diligence fees and oil and gas leases
is less than an amount equal to 42% of the capital contributions initially made
by investor partners to the related partnership, then we shall contribute to the
drilling program such additional funds in respect of tangible costs as may be
necessary to cause our aggregate contributions to the related drilling program
to be not less than 42% of the capital contributions initially made by investor
partners to the related partnership. Any amounts paid by us in respect of
organizational and offering expenses, sales commissions and due diligence fees
in excess of 15% of the capital contributions initially made by the investor
partners to the related partnership will not be considered in determining the
amount of our contribution.
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The following table shows the calculation of the maximum and minimum
amounts which will be contributed to each drilling program to be conducted by
each partnership.
MAXIMUM MINIMUM
CAPITAL CAPITAL
------- -------
Capital contributions of investor partners ............ $10,000,000 $1,000,000
Managing partner's capital contribution to the
partnership ........................................... 0 0
Initial partnership capital and total partnership funds
available for drilling program operations ............. 10,000,000 1,000,000
Plus:
Contributions of the managing partner as a participant
in the drilling program ............................... 4,200,000 420,000
TOTAL AMOUNTS TO BE CONTRIBUTED TO
EACH DRILLING PROGRAM ................................. $14,200,000 $1,420,000
The following table is a summary of the estimated expenditures to be
made with respect to the total contributions made to a partnership's drilling
program. The table assumes a partnership receiving the minimum total capital
contribution from investor partners of $1,000,000 and a corresponding
contribution of the managing partner as a participant in the drilling program of
$420,000. The percentages set forth in the table below are estimates only, and
we cannot assure that these percentage will be actually realized or that
variations in the percentages will not be significant to partnership or its
drilling program.
RANGE OF TOTAL DOLLAR
RANGE OF PERCENTAGES OF AMOUNT OF
CAPITAL CONTRIBUTIONS CAPITAL CONTRIBUTIONS
EXPENDED EXPENDED
--------------------- ---------------------
Organization and Offering Expenses 2.5% $35,000
Sales Commissions and Due Diligence Fees 5.9% $85,000
Lease Acquisition Costs of Prospects 15% - 20% $213,000 - $284,000
Tangible Costs 12% - 16% $170,400 - $227,200
Intangible Drilling Costs 55% - 60% $781,000 - $852,000
Other Costs 0% - 10% $0 - $142,000
The amount of organization and offering expenses described above will represent
approximately 3.5% of the capital contributions initially made by investor
partners to each partnership in exchange for their respective interests. The
amount of sales commissions and due diligence fee will equal 8% and .5%,
respectively, of the capital contributions initially made by investor partners
to each partnership in exchange for their respective interests.
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PARTICIPATION IN COSTS AND REVENUES
COSTS AND REVENUES
The combination of the allocation provisions contained in each
partnership agreement and the related drilling program agreement results in
aggregate allocations of revenues and costs, and income and gain relating to
revenues and costs, to the investor partners in a partnership and to the
managing partner on a consolidated basis are, in general, as set forth in the
table below.
Investor Managing
Partners Partner
-------- --------
Participation in Revenues:
Interest earned on capital contributions of investor partners .......... 100% --
Proceeds from disposition of depreciable property and depletable oil
and gas property ..................................................... 60% 40%
Revenues from operations ............................................... 60% 40%
Participation in Costs:
Organization and Offering Expenses, Sales Commissions
and Due Diligence Fees ............................................... 0% 100%
Operating Costs ........................................................ 60% 40%
Administrative Costs ................................................... 60% 40%
Reporting and Legal Expenses ........................................... 60% 40%
Lease Acquisition Costs funded by contributions ........................ 0% 100%
Intangible Drilling Costs funded by contributions ...................... 100% 0%
Tangible Costs funded by contributions ................................. 100% 0%
All other Direct Costs, including intangible drilling costs and
tangible costs that may be funded by revenues from operations ........ 60% 40%
All tangible costs shall be allocated entirely to the related
partnership; provided however, that to the extent, if any, that the total
contributions made by us for organization and offering expenses, sales
commissions and due diligence fees and lease acquisition costs are less than an
amount equal to 42% of the aggregate capital contributions initially made by
investor partners to that partnership, then we will be allocated an amount of
tangible costs equal to that deficit amount.
Proceeds from the sale of an oil and gas property, or depreciable
property, to the extent of a drilling program's simulated basis, or adjusted tax
basis, in the property will be allocated in accordance with the manner in which
costs attributable to such property's purchase were allocated up to an amount
equal to the drilling program's simulated basis, or adjusted tax basis, in such
property at the time of sale. Any remaining sale proceeds will be allocated to
the partners in a manner which will cause the total proceeds from such sale and
all prior sales to be allocated, to the extent possible, as if all such proceeds
had been allocated in the percentages indicated.
DISTRIBUTIONS
That portion of a partnership's revenues, if any, which in the sole
judgment of the managing partner are not required to meet the obligations of
that partnership including, but not limited to, the obligations of a partnership
to reimburse the managing partner and its affiliates for administrative costs
will be distributed to the investor partners not less often than quarterly.
Accordingly, there is no assurance that any distributions will be made to the
investor partners. See "Compensation and Reimbursement." Such reimbursements and
payments by a partnership reduce the amounts otherwise available for
distribution to the investor partners and create a risk that an investor
partner's share of the partnership's taxable income may be greater than the
amounts distributed to him. See "Tax Aspects -- Partnership Taxation --
General." Interest earned on aggregate capital contributions of the investor
partners will be
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allocated solely to the investor partners and will be distributed to them
periodically at such time or times as the managing partner shall determine.
CAPITAL ACCOUNTS
A capital account will be maintained by each partnership for each
partner and by each drilling program for each participant therein in the manner
described in "Tax Aspects -- Partnership Taxation -- Allocations."
ALLOCATIONS OF FEDERAL INCOME TAX ITEMS
All recapture of federal income tax deductions and credits resulting
from the sale or other disposition of partnership assets will be allocated among
the investor partners in the same proportions as the deductions or credits
giving rise to such recapture were allocated. Items of income, gain, loss,
deduction and credit are allocated for federal income tax purposes under the
drilling program agreement in accordance with the allocation of costs, revenues,
and expenses described above.
The partnership agreement provides that if during any fiscal year of a
partnership, the allocation of any loss or deduction, net of any income or gain,
to a partner would cause his capital account balance, as adjusted in accordance
with applicable Treasury Regulations, to be less than zero as of the end of such
fiscal year, or would increase a deficit balance, only the amount of such loss
or deduction that reduces the balance to zero shall be allocated to such deficit
partner. The remaining loss or deduction shall be allocated to the partners
having positive capital account balances.
After any such allocation, partnership income or gain that otherwise
would be allocated to the deficit partner which is in excess of the cash
distributions to the deficit partner for such fiscal year shall be allocated
instead to the partners having positive capital account balances until the
amount so allocated equals the amount of loss or deduction previously allocated
to the partners having positive capital account balances rather than to the
deficit partner under this provision.
In addition, if at the end of any fiscal year of a partnership the
capital account balance, as adjusted in accordance with applicable Treasury
Regulations by taking into account distributions and deductions reasonably
expected in subsequent years, of any partner is less than zero, partnership
income or gain otherwise allocable for such fiscal year to the partners having
positive capital account balances shall be allocated to such negative partner in
an amount necessary to cause such capital account balance to equal zero.
After any such allocation, the partnership gain resulting from the sale
or other disposition of partnership property that would otherwise be allocated
to the negative partner for any fiscal year shall be allocated instead to the
partners having positive capital account balances until the amount of such gain
or amount realized so allocated equals the amount of income or gain previously
allocated to such negative partner. See "Tax Aspects -- Partnership Taxation --
Allocations."
PROPORTIONATE INTERESTS OF PARTNERS
Distributions of cash and allocations of tax items among partners in a
partnership will be made in accordance with the proportion that the sharing
ratio of each partner in the partnership bears to the aggregate sharing ratios
of all partners in the partnership. A partner's sharing ratio is equal to the
amount determined by dividing that partner's capital contribution to a
partnership by the aggregate capital contributions of all partners to that
partnership.
In the event of a transfer or surrender of interests by an investor
partner, items of income, gain, loss, deduction, and credit will be allocated
between the transferring investor partner and the transferee based on the number
of days during the taxable year in which such transfer was made on which each
person owned such interests. For purposes of such allocations and for purposes
of the next following distribution of cash, except for cash attributable to a
sale of a depletable property, transfers of interests will be recognized, in
accordance with the
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partnership agreement, effective as of a date determined by the managing
partner, which is expected to be the first day of the month following the
recordation of the transfer in the books and records of the related partnership.
COMPENSATION AND REIMBURSEMENT
The managing partner and its affiliates will receive benefits, both
directly and indirectly, from its position as managing partner of the
partnerships and Mewbourne Oil Company's position as drilling program manager of
the drilling programs, which benefits may be considered to be compensation to
the managing partner and its affiliates. Such benefits consist of the following:
Form of Compensation/
Reimbursement Amount
Reimbursement - Administrative Costs Indeterminate - reimbursement based
upon allocation made in accordance
with generally accepted accounting
principles.
Compensation - operator Compensation initially based upon
participation share of $780 per
producing well per month charge and
$7,420 per drilling well per month
charge.
Compensation - partnership interest and Indeterminate - based upon
drilling program participation difference between the managing
participation partner's share of
drilling program revenues and the
managing partner's share of
drilling program costs.
Compensation - lending of funds to a Indeterminate - compensation based
partnership upon the lesser of lender's
incurred interest cost or the rates
chargeable by banks on comparable
loans.
Compensation - payment for equipment, Indeterminate - based upon
supplies and other services competitive prices.
PARTNERSHIP AND PROGRAM INTEREST
Under the terms of each drilling program agreement, the managing
partner as a participant in the drilling program will be required to make
contributions to the drilling program at a percentage which is lower than the
percentages of revenues to be received by the managing partner. Specifically,
the aggregate amount of contributions to be made by the managing partner to the
drilling program must equal at least 42% of the capital contributions initially
made by investor partners to the related partnership or 29.57% of the aggregate
contributions made by all participants to the drilling program, and all revenues
from drilling program operations, other than from disposition of depletable or
depreciable property, generally shall be allocated 60% to the investor partners
and 40% to the managing partner.
LEASE AND EQUIPMENT PURCHASES FROM MEWBOURNE
The managing partner as a participant under the terms of each drilling
program agreement will contribute to each drilling program the oil and gas
leases upon which the drilling program will conduct its operations. The managing
partner's contribution of oil and gas leases to the drilling program will be
credited to the drilling program at the lease acquisition costs or at fair
market value if the lease acquisition costs is materially more than fair market
value. In addition, a partnership may buy or lease supplies and equipment from
the managing partner or its affiliates for compensation, prices or rentals that
are no less favorable to a partnership than are generally available from
unrelated third parties in the area engaged in the business of selling or
leasing comparable supplies or equipment. See "Proposed Activities --
Transactions with Affiliates."
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ADMINISTRATIVE COSTS
The managing partner of each partnership, and the drilling program
manager of each related drilling program, will be entitled to reimbursement of
administrative costs and reporting and legal expenses incurred by them in
connection with managing and conducting the affairs relating to a partnership's
interest in the related drilling program or of the partnership, as applicable.
The amount of administrative costs that are reimbursed by a partnership shall be
allocated to the partnership and the related drilling program on a basis
conforming with generally accepted accounting principles and must be supported
in writing as to the application of such costs and as to the amount charged.
Regardless of the actual amount of administrative costs incurred by the managing
partner or drilling program manager in connection with the affairs of a
partnership, during any particular calendar year the total amount of
administrative costs allocable to that partnership shall not exceed the greater
of:
o 3.5% of the partnership's gross revenues from the sale of oil and
natural gas production during such year, calculated without any
deduction for Operating Costs or other costs and expenses, or
o the sum of $50,000 plus .25% of the capital contributions of general
and limited partners to such partnership.
The above limitation on administrative costs shall not be applicable to
administrative costs otherwise allocable to a partnership which are
extraordinary and non-recurring or to the fixed overhead fee chargeable by an
operator of oil and gas wells including the fixed overhead fee chargeable under
an operating agreement by Mewbourne Oil Company with respect to the oil and gas
wells operated by Mewbourne Oil Company.
Administrative Costs incurred by the managing partner and the drilling
program manager in respectively managing and conducting the business and affairs
of a partnership and the related drilling program will be allocated 60% to the
investor partners and 40% to the managing partner. The managing partner
anticipates that the amount of administrative costs allocated to a partnership
in 2000 will range between $15,000 to $25,000. These expenses are only estimates
and they may vary due to the amount of capital raised, the date a partnership is
funded, the costs actually incurred in the operation of a partnership and the
related drilling program, and inflationary trends. Such amount includes
administrative costs that the managing partner or its affiliates have incurred
or which it is estimated they will incur on behalf of a partnership, including
those relating to a partnership's interest in the related drilling program, in
the calendar year in which investor partners are first admitted to the
partnership, but before investor partners are admitted to the partnership.
Reporting and legal expenses will be allocated 60% to the investor
partners in the partnership and 40% to the managing partner. Reporting and legal
expenses are estimated to be $15,000 for a partnership for the first year
following the year in which investor partners are first admitted to the
partnership.
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ESTIMATED DRILLING PROGRAM EXPENSES
The managing partner estimates that direct costs that are in the nature
of reporting and legal expenses and administrative costs allocable to a
partnership for the first twelve months of operation will be approximately
$66,000. The managing partner estimates that the components of such allocable
amounts will be as follows:
Administrative Costs:
Legal.......................................................................... $ 1,000
Accounting..................................................................... 12,000
Geological..................................................................... 3,000
Secretarial.................................................................... 12,000
Travel......................................................................... 2,000
Office Rent.................................................................... 5,000
Telephone...................................................................... 3,000
Data Processing................................................................ 5,000
Other ......................................................................... 6,000
Other Direct Costs:
External Legal................................................................. $ 5,000
Audit Fees..................................................................... 7,000
Independent Engineering Reports(1)............................................. 5,000
TOTAL..................................................................... $66,000
The expenses shown above are estimates only and may vary due to the amount of
capital raised, the date a partnership is funded, the number of prospects or
leases acquired and the number of wells drilled by the partnership, the timing
and amount of the costs actually incurred in the operation of that partnership
and the related drilling program, and inflationary trends. In addition,
depending upon the timing of the funding and operation of a partnership the
engineering costs may not be incurred in the first twelve months.
CONTRACTS WITH MEWBOURNE AND ITS AFFILIATES
Neither the managing partner nor its affiliates owns any drilling rigs
or service companies, and except for the providing of gas compressors from an
affiliate of the managing partner, the managing partner currently does not
anticipate that it or its affiliates will enter into contracts with a
partnership for the rendering of services or the sale or lease of supplies and
equipment other than the operating agreement discussed below. Nevertheless, the
managing partner and its affiliates are permitted under the terms of the
partnership agreement to enter into contracts with a partnership for such
purposes and for the lending of money to the partnership under the limitations
established in the partnership agreement. The partnership agreement, however,
provides limitations on the circumstances under which such services may be
rendered and such sales may occur and the prices and rates that can be charged
therefor and for loans of money by the managing partner or its affiliates as
discussed in "Conflicts of Interest -- Contracts with Mewbourne and affiliates."
COMPENSATION AS OPERATOR
Except for limited instances described in the drilling program
agreement, the drilling program manager has agreed to act as operator with
respect to drilling and production operations to be conducted on program wells.
The drilling program manager will be entitled to be reimbursed for such services
in an amount equal to all charges, including overhead charges, which constitute
direct and indirect charges under an operating agreement or other applicable
operating agreement, including, for each program well, an initial fixed rate
overhead charge for each producing well of $780 per month and a fixed rate
overhead charge for each drilling well of $7,420 per month. However, any charges
by the drilling program manager or its affiliates to a partnership under an
operating agreement or other applicable agreement for the use of the drilling
program manager's or the affiliate's personnel, properties, and equipment, as
well as the pricing of materials purchased by a partnership from the drilling
program manager or the affiliates or by the drilling program manager or the
affiliates from a partnership, will be subject to limitations
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imposed in the partnership agreement. "Proposed Activities -- Operations" and
"Conflicts of Interest." In no event shall the consideration received for
operator services duplicate any other consideration or reimbursements received
under the drilling program agreement.
DEFINITIONS
The following are definitions of certain terms used in this prospectus.
In order to fully understand the terms of this offering, you should read these
definitions carefully.
"affiliated program" means a drilling, producing property, income,
royalty, or other program, whether in the form of a partnership, joint venture,
or otherwise, including the partnerships, for or of which the managing partner
or an affiliate of the managing partner serves as manager or managing partner or
acts in a similar capacity.
"development well" means a well drilled within the proved area of an
oil or gas reservoir to the depth of a stratigraphic zone or horizon known to be
productive. Development wells include, without limitation,
o a well drilled as an additional well to the same reservoir as
another producing well on an oil and gas lease,
o a well drilled to the same reservoir which previously contained a
producing well, drilled on an offset oil and gas lease to the
same reservoir, or
o a well drilled on acreage reasonably certain, based on accepted
geological, geophysical, and engineering studies and data, to be
geologically contiguous with the same reservoir.
"direct costs" means all actual and necessary costs directly incurred
for the benefit of a drilling program and generally attributable to the goods
and services provided to the drilling program by parties other than the managing
partner or its affiliates. Direct costs shall not include any cost otherwise
classified as organization and offering expenses, administrative costs,
operating costs, or lease acquisition costs. Direct costs also include the costs
of services provided by the managing partner or its affiliates under the terms
of written contracts. The term Direct Costs include reporting and legal expenses
and expenditures and costs that would otherwise be classified as intangible
drilling costs or tangible costs if they were not funded by revenues from
operations.
"eligible citizen" means any person who is eligible to be qualified to
hold an interest in oil and gas leases on federal lands, including offshore
areas, under federal laws and regulations in effect from time to time. As of the
date of this prospectus, in order to be an eligible citizen a person must
(a) be a citizen of the United States,
(b) not be a minor, unless a legal guardian or trustee holds the
interest on the minor's behalf,
(c) be in compliance with federal acreage limitations, and
(d) not be participating in any agreement, scheme, plan, or
arrangement related to simultaneous oil and gas leasing that
would otherwise be prohibited.
Under current federal oil and gas leasing rules,
(i) an association, including a partnership or a trust, is considered
an eligible citizen if both such association and all of its
members or partners, and all parties who own, hold, or control
any of its instruments of ownership or control, satisfy
requirements (a) through (d) above and
(ii) a corporation is considered an eligible citizen if it is
organized or existing under the laws of the United States, a
state, the District of Columbia, or a United States territory and
if it and all parties who own,
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hold, or control any of its instruments of ownership or control
satisfy requirements (a) through (d) above. For purposes of this
clause (ii), aliens from countries that the federal government
regards as not denying similar privileges to citizens or
corporations of the United States may own, hold, or control stock
in an eligible citizen.
In addition, an eligible citizen may not hold, own, or control, directly or
indirectly, interests in federal oil and natural gas leases, options for such
leases or interests in such leases, on lands subject to the United States
Mineral Lease Act of 1920, as amended, in excess of the following limits:
o 246,080 acres, of which no more than 200,000 may be under option,
in any one state other than Alaska and
o 300,000 acres, of which no more than 200,000 may be under option,
in each of the northern and southern leasing districts of Alaska.
"exploratory well" means
o a well drilled to find commercially productive hydrocarbons in an
unproven area, or
o a well drilled to find a new commercially productive zone or
horizon in a field previously found to be productive of
hydrocarbons at another zone or horizon, or to significantly
extend a known prospect.
"intangible drilling costs" means expenditures associated with the
drilling and completion of oil and gas wells that under present law are
generally accepted as fully deductible currently for federal income tax
purposes. intangible drilling costs include all expenditures made with respect
to any well prior to, and in preparation of, establishment of production in
commercial quantities. The term intangible drilling costs shall not include
lease acquisition costs. The term intangible drilling costs shall not include
expenditures that are funded by revenues from operations.
"lease acquisition costs" means, when used to describe the costs of any
oil and gas lease, the sum of
(a) all monetary consideration paid or given for the oil and gas
lease to a non-affiliate of the managing partner, including but
not limited to lease bonuses and advance rentals paid to a
non-affiliate of the managing partner,
(b) all costs of lease acquisition and title examination including
but not limited to curing or defending title, title insurance or
examination costs, brokerage commissions, the fees and wages of
landsmen and lease brokers and their expenses, filing fees,
recording costs, transfer taxes, and like charges paid in
connection with the acquisition of the oil and gas lease,
(c) all delay rentals and other similar payments and ad valorem taxes
paid by the seller with respect to the oil and gas lease,
(d) such portion as may be allocated to the oil and gas lease in
accordance with generally accepted accounting principles and
industry standards of all reasonable, necessary, and actual costs
and expenses of the managing partner or its affiliates for
geological, geophysical, seismic, land, engineering, drafting,
accounting, legal, and other like services together with related
administrative and general overhead costs involved in lease
acquisition and prospect evaluation including such costs and
expenses which could otherwise be classified in this prospectus
as administrative costs,
(e) such portion as may be allocated to the oil and gas lease in
accordance with generally accepted accounting principles and
industry standards of all costs and expenses incurred in the
acquisition of farmouts, subleases, pooling orders, or other oil
and gas interests,
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(f) interest and points actually incurred on funds borrowed to pay
any of the costs and expenses described in clauses (a) through
(e) above calculated from the date of their incurrence until the
date of their reimbursement by a drilling program at the time the
oil and gas lease is acquired by the drilling program, and
(g) with respect to oil and gas leases held on the date of this
prospectus by or acquired after such date by the managing partner
or an affiliate of the managing partner, an interest in which is
transferred to the participants pursuant to the drilling program
agreement, the costs of such transfer; provided that the expenses
described in clauses (c), (d), (e), and (f) shall have been
incurred by the managing partner or its affiliates not more than
36 months prior to the acquisition by a drilling program of the
oil and gas lease; and provided further, that such time
limitation shall not be applicable to an oil and gas lease having
a primary term of five or more years.
Lease Acquisition Costs of an oil and gas lease shall not include any costs or
expenses which represent costs or expenses incurred in connection with the past
drilling of wells which are not producers of sufficient quantities of oil or
natural gas to make commercially reasonable their continued operation.
"operating agreement" means a model form operating agreement based upon
the American Association of Petroleum Landsmen Form 610-1989. This operating
agreement includes the accounting procedure for joint operations issued by the
Council of Petroleum Accountants Societies of North America which is attached as
an exhibit to such agreement. An operating agreement will contain modifications
that are customary and usual for the geographic area in which the partnership
intends to conduct operations.
"operating costs" means all expenditures made and costs incurred in
producing and marketing oil and gas from completed wells. Operating costs
include labor, fuel, repairs, hauling, materials, supplies, utility charges,
other costs incidental to or resulting from such costs, ad valorem and severance
taxes, insurance, casualty loss expense, and compensation to well operators or
others for services rendered in conducting such operations.
"organization and offering expenses" means all costs and expenses
incurred by the managing partner and its affiliates in connection with the
organization of a partnership and a drilling program, the registration of the
interests for offer and sale under applicable federal and state securities laws,
and the offer and sale of the interests. Organization and offering expenses
include, without limitation, fees paid to persons performing due diligence
examinations or otherwise acting in relation to a partnership or the managing
partner with respect to the offering and sale of the interests and all expenses
reasonable for the managing partner and its affiliates incurred in assisting
with the distribution of the interests or such due diligence. Organizational and
offering expenses shall not include any costs and expenses that might be
categorized as any of the foregoing but that are included as sales commissions
or due diligence fees.
"proved reserves" means those quantities of crude oil, natural gas, and
natural gas liquids which, upon analysis of geological and engineering data,
appear with reasonable certainty to be recoverable in future years from known
oil and gas reservoirs under existing economic and operating conditions. Proved
Reserves are limited to those quantities of oil and gas which can be expected,
with little doubt, to be recoverable commercially at current prices and costs,
under existing regulatory practices and with existing conventional equipment and
operating methods. Depending upon their status or development, Proved Reserves
will be subdivided into the following classifications and have the following
definitions.
o "proved developed reserves" means proved reserves which can be
expected to be recovered through existing wells with existing
equipment and operating methods. Additional oil and gas expected
to be obtained through the application of improved recovery
techniques are included as proved developed reserves only after
testing by a pilot project or after the operation of an installed
program has confirmed through production that increased recovery
will be achieved.
o "proved undeveloped reserves" means all reserves which are
expected to be recovered from additional wells on undrilled
acreage or from existing wells where a relatively major
expenditure is required for
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recompletion. Such reserves on undrilled acreage are limited to
those drilling units offsetting productive units which are
reasonably certain of production when drilled. Proved reserves
for other undrilled units are claimed only where it can be
demonstrated with reasonable certainty, based on accepted
geological, geophysical, and engineering studies and data, that
there is continuity of reservoir from an existing productive
formation. No estimates for Proved undeveloped reserves are
attributable to any improved recovery technique contemplated for
any acreage, unless the techniques to be employed have been
proved effective by actual tests in the same areas and reservoir.
"reporting and legal expenses" means all third party accounting fees,
costs, and expenses associated with obtaining audits of books and records, third
party engineering fees, costs, and expenses associated with annual reserve
reports, and third party attorney's fees and other legal fees, costs, and
expenses associated with matters that are attributable to a drilling program's
or a partnership's business.
"sharing ratio" means for any partner in a partnership the proportion
obtained by dividing
o the amount of such partner's capital contribution to the
partnership by
o the sum of all capital contributions paid by all partners to that
partnership.
In the event of a voluntary or involuntary assignment by a partner of interests
in a partnership, other than an assignment solely of an interest in
distributions of partnership revenues, the sharing ratio of such partner shall
be proportionately reduced, based upon the number of interests assigned compared
to the total number of interests owned by such partner. The assignee of such
interests shall succeed to a proportionate share of the sharing ratio of his
assignor that is attributable to the interests transferred to such assignee.
"sponsor" means any person directly or indirectly instrumental in
organizing, wholly or in part, a partnership or any person who will manage or is
entitled to manage or participate in the management or control of a partnership.
Sponsor includes the managing partner and any other person who actually controls
or selects any person who controls 25% or more of the exploratory,
developmental, or producing activities of a partnership or any segment of the
partnership, even if that person has not entered into a contract at the time of
the formation of the partnership. Sponsor does not include wholly independent
third parties such as attorneys, accountants, and underwriters whose only
compensation is for professional services rendered in connection with the
offering of the interests. The term Sponsor shall also be deemed to include its
affiliates.
"tangible costs" means those costs associated with drilling and
completion of oil and gas wells which are generally accepted as capital
expenditures under the Internal Revenue Code of 1986, as amended. Tangible costs
include all costs of equipment, parts and items of hardware used in drilling and
completing a well. Tangible costs also include those items necessary to deliver
acceptable oil and gas production to purchasers to the extent such items are
installed downstream from the wellhead of any well and which are required to be
capitalized under applicable provisions of the Internal Revenue Code and the
regulations promulgated under the Internal Revenue Code. The term tangible costs
shall not include costs that are funded by revenues from operations.
TERMS OF THE OFFERING
GENERAL
Mewbourne Development Corporation, as managing partner, is offering to
qualified investors during 1999 and 2000 an aggregate of up to 4,000
($4,000,000) limited partner interests and up to 16,000 ($16,000,000) general
partner interests in a series of two partnerships. The minimum offering amount
for a partnership is 1,000 interests ($1,000,000) with the maximum offering
amount being 10,000 interests ($10,000,000). Each partnership will be a distinct
entity, and a purchaser of interests in any one partnership will not obtain an
interest in the other partnership. No partnership will commence operations prior
to the termination of the subscription period for interests. Each partnership
will participate, together with us and our affiliate Mewbourne Oil Company, in a
drilling program.
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Under the drilling program agreement, the activities of each partnership will
focus upon the acquisition of oil and gas leases covering prospects, the
drilling of development wells and the production and operation of the resulting
properties.
The minimum subscription in a partnership is five interests ($5,000).
The entire purchase price for each interest must be paid in cash at the time of
subscription.
The execution of a subscription agreement in the form attached as
Exhibit D to this prospectus by a subscriber or his authorized representative
constitutes a binding offer to buy interests in a partnership and an agreement
to hold the offer open until the subscription is accepted or rejected by the
managing partner. Once an investor subscribes for interests, he will not have
any revocation rights other than rights under applicable securities laws. The
managing partner may refuse to accept any subscription without liability to the
subscriber. The managing partner may reject a subscription if, for example, the
prospective investor does not satisfy the suitability standards or if the
subscription is received after the offering period has terminated. The execution
of a subscription agreement and its acceptance by the managing partner also
constitute the execution of the partnership agreement and an agreement to be
bound by the terms of the partnership agreement as an investor partner,
including the granting of a special power of attorney to the managing partner
appointing it as the investor partner's lawful representative to make, execute,
sign, swear to, and file various documents and instruments. See "Summary of
Partnership Agreement and Drilling Program Agreement -- Power of Attorney."
The managing partner and its affiliates are eligible to subscribe for
interests, provided that any interests so purchased must be purchased for
investment purposes only and not for the purpose of resale or any further public
distribution. It is the managing partner's current intention that the managing
partner and/or its affiliate will subscribe for such number of interests as may
be necessary for each partnership to receive the minimum subscription amount of
1,000 interests ($1,000,000). The number of interests in a partnership that may
be purchased by the managing partner and/or its affiliates is not subject to any
specific maximum limitations but depends upon the number of subscriptions for
interests received and accepted from non-affiliates. However, although there are
no limitations upon the number of interests that may be purchased by the
managing partner or its affiliates, the managing partner does not intend to
purchase any interests in a partnership if the partnership has already received
the minimum subscription amount and the managing partner does not intend to
purchase any more interests in a partnership than necessary to ensure that such
partnership receives the minimum subscription amount. Subject to limitations,
interests purchased by the managing partner or its affiliates will have voting
rights under the partnership agreement. See "Risk Factors -- Particular Risks
Relating to the Interests -- Ownership of Interests by Our Affiliates.
SUBSCRIPTION REFUNDS
If, within 12 months after the admission of the general and limited
partners to a partnership, the partnership has not expended or committed for
expenditure an amount equal to the total capital contributions of the
partnership's investor general and limited partners, the managing partner shall
distribute, as a return of capital, to the general and limited partners on a pro
rata basis the amount of such unexpended and uncommitted partnership funds,
after deducting an amount that the managing partner reasonably determines will
be equal to the operating capital to be required by that partnership that will
not be provided by anticipated revenues from partnership operations. For a
description of the tax consequences resulting from the distribution of such
uncommitted amounts, see "Tax Aspects -- Special Features of Oil & Gas Taxation
- -- Basis and At Risk Rules."
SUBSCRIPTION PERIOD
The offering of interests in Mewbourne Energy Partners 99-A, L.P.
commenced on August 10, 1999 and terminated on November 22, 1999. A total of 676
($676,000) limited partner interests and 5,051 ($5,051,000) general partner
interests in Mewbourne Energy Partners 99-A, L.P. were sold to a total of 29
persons and 208 persons, respectively.
The subscription period for interests in Mewbourne Energy Partners
00-A, L.P. will commence on the date of this prospectus and terminate on
November 1, 2000, unless we, as managing partner, in our sole discretion,
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accelerate or delay the offering termination date, provided that our ability to
delay the offering termination date is subject to our obligation to return the
purchase price for any interests not invested in a partnership within any period
required by state securities law.
A partnership shall not be funded with less than $1,000,000 in capital
contributions from investor general and limited partners. If, at the end of the
subscription period for interests in a partnership, subscription funds of less
than $1,000,000 have been received by us, such funds will be promptly returned
to subscribers.
SUITABILITY STANDARDS
General.
Investment in a partnership involves a high degree of financial risk
and is suitable only for persons of substantial means who have no need for
liquidity in their investment and who can afford to lose all or substantially
all of their investment. In particular, investment as a general partner is
recommended only to those persons who are in a position to benefit from the
treatment given such investment under current federal income tax laws. The
following suitability requirements represent the minimum suitability
requirements for investors in a partnership, and the satisfaction of such
requirements by a prospective investor does not necessarily mean that an
investment in a partnership is a suitable investment for that investor.
Based upon the information provided by each subscriber concerning
his/her investment objectives, other investments, financial situation and needs,
and any other pertinent information, each person offering and selling interests
is required to make every reasonable effort to assure that the purchase of
interests and an investment in a partnership are an appropriate investment for
an investor in light of the suitability standards set forth in this prospectus
and that an investment in interests is consistent with such investor's
investment objectives and financial situation. In addition, such persons will
make every reasonable effort to assure that:
o such subscriber is or will be in an appropriate financial
position which will enable him/her to realize to a significant
extent the benefits described in this prospectus, including the
tax benefits,
o the subscriber has a fair market net worth sufficient to sustain
the risks inherent in an investment in a partnership, including
loss of investment and lack of liquidity,
o an investment in a partnership is otherwise suitable for such
subscriber, and
o they have a reasonable basis to believe that the subscriber,
along or with one or more representatives, advisors, or agents
has the knowledge and experience in financial and business
matters to be capable of evaluating the merits and risks of the
offering.
Such information will be maintained by the managing partner and the applicable
soliciting dealer for at least six years.
Minimum Suitability Standards
Each subscriber for interests must represent in writing that he/she
has:
o a minimum annual gross income of $60,000 and a minimum net worth
of $60,000 exclusive of home, home furnishings and automobiles,
or
o a minimum net worth of $225,000 (exclusive of home, home
furnishings and automobiles).
Investors who are residents of the states set forth below may be
subject to higher and/or alternative suitability standards, which are described
below. Additional representations and warranties required of general and
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limited partners are set forth in the special subscription instructions and the
subscription agreement attached as Exhibits C and D to this prospectus.
Additional Suitability Standards.
For ALABAMA, ARIZONA, IOWA, KANSAS, MAINE, MASSACHUSETTS, MICHIGAN,
MISSISSIPPI, MISSOURI, NEW MEXICO, NORTH CAROLINA, OHIO, OREGON, PENNSYLVANIA,
SOUTH CAROLINA, SOUTH DAKOTA, TENNESSEE, TEXAS, UTAH, VIRGINIA, WASHINGTON AND
WEST VIRGINIA, RESIDENTS. A resident of the States of ALABAMA, ARIZONA, IOWA,
KANSAS, MAINE, MASSACHUSETTS, MICHIGAN, MISSISSIPPI, MISSOURI, NEW MEXICO, NORTH
CAROLINA, OHIO, OREGON, PENNSYLVANIA, SOUTH CAROLINA, SOUTH DAKOTA, TENNESSEE,
TEXAS, UTAH, VIRGINIA, WASHINGTON, AND WEST VIRGINIA, and who are subscribers
for general partner interests must represent in writing that he/she has:
o minimum net worth of $225,000 without regard to the investment in
the partnership, exclusive of home, home furnishings and
automobiles, and as to the residents of Alabama, Maine,
Massachusetts, North Carolina, Ohio, Pennsylvania, South
Carolina, Tennessee, Texas, Utah, Virginia, Washington and West
Virginia a minimum annual gross income of $100,000 for the
current year and for the two previous years, and as to residents
of Arizona, Iowa, Kansas, Michigan, Mississippi, Missouri, Oregon
and South Dakota a taxable income of $60,000 or more for the
previous year and the expectation of an annual taxable income of
$60,000 or more for the current year and for the next succeeding
year, or
o a minimum net worth in excess of $1,000,000, inclusive of home,
home furnishings, and automobiles, or
o a minimum net worth of $500,000, exclusive of home, home
furnishings and automobiles, or
o a minimum annual gross income of $200,000 in the current year and
the two previous years.
The subscriber must also represent in writing that the investment in a
partnership does not represent more than ten percent of the subscriber's net
worth, less the value of the subscriber's other investments in limited
partnership interests.
For CALIFORNIA Residents. A resident of the State of CALIFORNIA who
subscribes for limited partner interests must represent in writing that he/she
has:
o a net worth of at least $250,000 or more, exclusive of home, home
furnishings, and automobiles and had during the last tax year or
estimates that he/she will have during the current tax year, a
gross annual income of $65,000 or more, or
o a net worth of $500,000 or more, exclusive of home, home
furnishings, and automobiles.
A resident of the State of CALIFORNIA who subscribes for general
partner interests must represent in writing that he/she has:
o a net worth of at least $250,000 or more, exclusive of home, home
furnishings, and automobiles and had during the last tax year, or
estimates that he/she will have during the current tax year, a
gross annual income of $120,000 or more, or
o a net worth of $500,000 or more, exclusive of home, home
furnishings, and automobiles, or
o a net worth of $1,000,000 or more, inclusive of home, home
furnishings, and automobiles, or
o had during the last tax year, or estimates that he/she will have
during the current tax year, a gross annual income of $200,000 or
more.
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For MICHIGAN and OHIO Residents. A resident of MICHIGAN OR OHIO must
represent that the investment in a partnership does not exceed ten percent of
the subscriber's individual or joint net worth, exclusive of home, home
furnishings, and automobiles.
For NEW HAMPSHIRE Residents. A resident of the State of New Hampshire
who subscribes for interests must, at a minimum, represent in writing that
he/she has:
o an individual net worth of at least $250,000, exclusive of home,
home furnishings, and automobiles, or
o an individual net worth of at least $125,000, exclusive of home,
home furnishings, and automobiles, and $50,000 of taxable income.
For TENNESSEE Residents. A resident of the State of TENNESSEE who
subscribes for interests must, at a minimum, represent in writing that he/she
has:
o an individual net worth of at least $250,000, exclusive of home,
home furnishings, and automobiles, and had during the last tax
year and estimates that he/she will have during the current tax
year, a gross income of at least $65,000, or
o a net worth of at least $500,000, exclusive of home, home
furnishings, and automobiles.
Additional Requirements.
Fiduciary Accounts. In the case of sales to IRAs, Keogh Plans, various
employee benefit plans and other similar fiduciary accounts. The suitability
standards may be met by the account or by each beneficiary of the account, or
where the fiduciary is the donor of the funds for investment in a partnership,
the suitability standards may be met by the fiduciary. These subscribers should
also carefully review the discussion under "Tax Aspects -- General Tax
Provisions -- Investment by Tax-Exempt Entities," which indicates, among other
things, that substantially all of the income from a partnership's operations
will constitute "unrelated business taxable income" for tax purposes and may
give rise to tax liability to the investor.
For CALIFORNIA Residents. Assignability or transfer of an interest is
limited so that no assignee or assignor, transferee or transferor may hold less
than $5,000 in interests. See the special subscription instructions attached as
Exhibit C to this prospectus for restrictions that limit the transferability of
interests.
For NORTH CAROLINA Residents. The minimum subscription in a partnership
is five interests ($5,000). Although the managing partner may accept joint
ownership of interests, the minimum initial cash investment by each person
having such joint ownership may not be less than $5,000.
It is anticipated that each partnership will acquire interests in
federal oil and gas leases, thus subscriptions for interests will not be
accepted from a person who is not an eligible citizen. In general, an eligible
citizen is any person who is a citizen of the United States or is otherwise
eligible to be qualified to hold an interest in oil and gas leases on federal
lands, including offshore areas, under federal laws and regulations in effect
from time to time. Each prospective investor must represent in writing that he
or she is an eligible citizen.
For Transferees of Interests. Transferees of interests seeking to
become substitute general and limited partners must also meet the suitability
requirements discussed above, provided that the requirements with respect to net
worth and taxable income may be waived at the managing partner's discretion
under limited circumstances, including transfers of interests by an investor
partner to a dependent or to a trust for the benefit of a dependent or transfers
by will, gift, or by the laws of descent and distribution.
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SUBSCRIPTION PROCEDURE
An eligible subscriber may subscribe for interests in a partnership
prior to the end of the subscription period for the partnership by properly
completing, executing, and delivering the following documents to his soliciting
dealer:
o A subscription agreement in the form attached as Exhibit D to
this prospectus; and
o A check payable to the order of "Bank of America of Texas, Escrow
Agent for Mewbourne 99-00 Drilling Program" in an amount equal to
the purchase price for the number of interests to be purchased by
that investor.
The managing partner will not accept any subscription agreement that
has been executed by someone other than the investor, except a subscription
agreement on the part of a fiduciary account that has been executed by an
individual having the legal power of attorney to so act. Unless a subscription
is rejected by the managing partner at any time prior to the admission of
general and limited partners to a partnership or the managing partner elects not
to admit general and limited partners to a partnership, fully paid subscriptions
in proper form will be deemed accepted, subject to reduction in accordance with
the subscription agreement. By its terms, the subscription agreement constitutes
a binding agreement of the subscriber. Subject to the right of the managing
partner to reject subscriptions, each subscriber will become an investor partner
in a partnership at the time he is admitted to the partnership. General and
limited partners will be admitted to a partnership contemporaneously with the
release of the funds from the escrow account, and thereafter general and limited
partners will be admitted to a partnership not later than the last day of the
calendar month in which their subscriptions were accepted by the managing
partner. Subscriptions will be accepted or rejected by the managing partner
within 30 days of their receipt or such other shorter time period as may be
required by applicable laws of the state in which the subscriber resides. If a
subscription is rejected, the subscription funds tendered in connection
therewith will be immediately returned to the appropriate subscriber without
interest or deduction for expenses. If general and limited partners are not
admitted to a partnership on or before the expiration of the subscription period
for interests in that partnership, all subscription funds relating to that
partnership will be immediately returned in full, together with any interest
thereon, to the appropriate subscribers.
Subscription funds will be deposited in an escrow account at Bank of
America of Texas, N.A., Tyler, Texas, or another federally insured institution
designated by the managing partner; provided that upon receipt and clearance of
aggregate subscription funds of $1,000,000 or more from subscribers that the
managing partner deems suitable to be general and limited partners in a
partnership, the managing partner may, upon written request, cause those
subscription funds to be withdrawn from the escrow account and to be deposited
in an account established for that partnership and all subscribers whose
subscriptions have been accepted shall be admitted as an investor partner in
that partnership within 15 days after such deposit. Thereafter, subscription
funds will be deposited in a partnership account with each subscriber whose
subscription has been accepted being admitted as an investor partner in that
partnership no later than the last day of the calendar month in which such
subscription was accepted. Until subscribers are admitted as general or limited
partners in a partnership, no expenses may be paid from the partnership account.
Each subscriber whose subscription has been accepted and who has been admitted
as an investor partner will be provided confirmation of such acceptance and
admission. Funds deposited in the escrow account or partnership account will be
invested in time deposits, short-term bank certificates of deposit, short-term
governmental obligations, U.S. treasury bills, or bank money market accounts and
similar investments until those funds are expended for partnership operations.
A subscriber whose funds are deposited in the escrow or partnership
account no fewer than five business days prior to the termination of the
subscription period for interests in the partnership will receive, within 60
days following the admission of such subscriber as an investor partner in the
partnership, interest earned on those funds from the date those funds cleared
the institution where that account is maintained and are invested to the date on
which such subscriber was admitted to the partnership as an investor partner in
the partnership. Although subscription funds generally clear an institution
within three to five business days following their deposit, no assurance can be
given that those proceeds will be clear within that period of time. All
subscription funds, together
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with any interest earned thereon, will be promptly returned to each subscriber
that is not admitted as an investor partner to a partnership.
After the subscription period for a partnership has expired, no
additional interests in the partnership will be offered or sold. Notice of the
admission of general and limited partners to a partnership and the percentage of
ownership of each investor partner in that partnership will be furnished to each
investor partner following their admission to the partnership.
Pending their use in partnership activities, the managing partner
intends to invest the balance of the capital contributions in time deposits,
short-term governmental obligations, U.S. treasury bills, money market accounts,
commercial paper and similar investments. Any interest earned on capital
contributions from investor general and limited partners will be allocated
solely to the investor general and limited partners, and will be distributed to
the general and limited partners periodically. See "Participation in Costs and
Revenues." Funds of a partnership will not for any purpose be commingled with
funds of any partnership, the managing partner or an affiliate of the managing
partner or any other entity.
NO SUBSCRIPTION AGREEMENT WILL BE ACCEPTED UNTIL AT LEAST 5 BUSINESS
DAYS HAVE ELAPSED FROM THE DATE THAT THE SUBSCRIBER RECEIVED A COPY OF THIS
PROSPECTUS.
CONVERSION OF GENERAL PARTNER INTERESTS
We anticipate that the general partner interest in a partnership held
by a general partner will be converted to a limited partner interest in that
partnership following the completion of that partnership's drilling activities;
which we anticipate will occur within approximately 8 to 15 months after the
funding of that partnership. Generally, the discussion in this prospectus
relating to limited partners and limited partner interests, other than the
discussion of the federal income tax consequences of an initial investment as a
limited partner, will apply to converted partners after the time of such
conversion. However, converted partners will continue to have the rights and
obligations of general partners with respect to activities occurring prior to
conversion, including liability for the partnership's obligations. See
"Liability of General and Limited Partners -- General Partners." Furthermore,
the tax treatment of converted partners will in some respects be determined by
their previous status as general partners. See "Tax Aspects -- Partnership
Taxation -- Conversion of General Partner Interests" and "Tax Aspects -- Special
Features of Oil and Gas Taxation -- Passive Activity Loss Limitations." If the
managing partner determines that the conversion of the general partner interests
in a partnership to limited partner interests will have an adverse effect on the
general partners or the partnership, due to adverse tax consequences or other
reasons, the managing partner may delay the conversion or may elect not to
convert the general partner interests; provided that if the managing partner
determines that such conversion would not be in the best interests of the
general partners or the partnership, the insurance coverage limits as set forth
under "Proposed Activities -- Insurance" will not be reduced unless such
coverage becomes unobtainable or is only available at premiums which are
prohibitively more expensive than the premiums now being paid for such policies.
RIGHT OF PRESENTMENT
Each investor partner in a partnership may request in writing that the
managing partner purchase for cash all, but not less than all, of that investor
partner's interests on the terms and subject to the limitations set forth below.
The managing partner may cause its affiliate to fulfill its obligation to
purchase an investor partner's interests. Partners in a partnership formed in
1999 may make this request in each of the years 2003 through 2008 and partners
in a partnership formed in 2000 may make this request in each of the years 2004
through 2008. The managing partner, acting in its sole discretion, shall have
the right, but not the obligation, to extend either or both of the time periods
in which an investor partner may make this request. Any such extension must be
made for a period of at least one year and in yearly increments. Should the
managing partner elect to make an extension, then the managing partner shall
give notice to the investor partners of the extension on or before January 31 of
the last year in which the right of presentment then may be exercised. If the
interests are subsequently listed on a national securities exchange or are
traded through the National Association of Securities Dealer's Automated
Quotation System or in the over-the-counter market, this right of presentment
may be terminated at any time at the option of the managing partner. Any
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such listing could have an adverse effect on the tax consequences of an
investment in interests. See "Tax Aspects - Partnership Taxation." If the
obligation of the managing partner or its purchaser designee to purchase
interests from general and limited partners is determined to violate any
existing or future laws, such obligation will be eliminated or modified
appropriately.
The obligation of the managing partner to purchase interests in a
partnership in any single calendar year is limited to no more than 5% of the
total number of interests of that partnership outstanding at the beginning of
such calendar year; provided, however, the total amount of funds that the
managing partner directly and by means of a purchaser designee is required to
expend in any single calendar year to purchase partnership interests from
investors in all of the oil and gas drilling partnerships as to which the
managing partner or an affiliate of the managing partner serves as sponsor shall
not exceed $500,000. Additionally, if subsequent to December 31 of the year
immediately preceding the year in which the right of presentment is being
exercised, the price for either oil or gas received by a partnership from its
program wells decreases by 20% or more as compared to the price being received
as of that date, then the managing partner may in its sole and absolute
discretion refuse to purchase any interests in that partnership.
During the first calendar quarter of each of the years during which the
right of presentment exists, each investor partner in a partnership may request
in writing that the managing partner purchase all, but not less than all, of his
interests. Prior to May 31 of each such year, the managing partner will notify
each requesting investor partner of the amount that the managing partner or its
purchaser designee will pay to purchase each interest and those general and
limited partners shall have twenty (20) days from the receipt of that notice in
which to elect whether to present their interests for purchase. If a greater
number of interests are presented than the managing partner is required to
purchase, the interests to be purchased will be selected by lot or by such other
method as the managing partner deems reasonable. Interests that are not
purchased will not have any priority with respect to purchase in subsequent
years.
The purchase price paid to an investor partner upon repurchase of his
interests in a partnership will be the pro rata share represented by his
interests of the sum of:
o 65% of the value of future net revenues attributable to proved
developed producing reserves of that partnership, and
o 50% of the value of future net revenues attributable to proved
developed non-producing reserves of that partnership, as such are
determined by an independent expert selected by the managing
partner and after such value has been discounted as described
below, less the share of that partnership's debts, expenses, and
obligations of all kinds incurred and then allocable to those
interests.
The purchase price will be determined as of December 31 of the year
immediately preceding the year in which the right of presentment is being
exercised. Any cash distributions to an investor partner after December 31 and
before the date of purchase attributable to the interests being repurchased will
be deducted from the purchase price for his interests. The effective date of any
such sale for purposes of determining such deduction will be deemed to be the
day on which payment of the purchase price is tendered by the managing partner
or its purchaser designee.
In order to compute the price to be paid upon the purchase of
interests, a partnership will cause an independent expert to estimate annually
the future net revenues attributable to the partners' interests in that
partnership's proved reserves based upon then current costs and pricing for oil
and gas as of the December 31 of the year immediately preceding the year in
which the right of presentment is being exercised. Such future net revenues
attributable to proved reserves:
o will first be adjusted by the independent expert to reflect the
risks of production and development of such reserves and any
other economic contingencies that normally would be considered by
a purchaser of proved reserves and
o will then be discounted to present value at a rate equal to 10%.
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A selling investor partner will be entitled to no further partnership
distributions with respect to the interests he has sold after the date on which
payment of the purchase price is tendered by the managing partner or its
purchaser designee.
Although the managing partner anticipates that its financial resources,
including its borrowing capabilities, will be sufficient to meet its purchase
obligations under the right of presentment, no assurance can be given that
contingencies will not arise which will require funding beyond the financial
resources committed to it. Therefore, there can be no assurance that either the
managing partner or its affiliates will have sufficient funds available to meet
the obligation to purchase interests from investors exercising the right of
presentment. If the managing general partner assigns or transfers its interest
in a partnership, the assignee of such interest will be required to assume the
withdrawing managing partner's obligations with respect to the right of
presentment.
An investor who sells his interests by exercising the right of
presentment may receive more or less total consideration than would be received
if the election to sell had not been made and, depending upon the success of the
partnership's activities and the timing of the sale, may realize a gain or loss
on such sale. Appraisals of future net recoverable reserves of oil and gas and
estimates of future net revenues to be received from such reserves are based on
variable and uncertain factors and assumptions, including the price at which
production can be sold, and amounts of actual production and net revenues will
vary from the estimates. Estimates made during the first few years of production
from a property will be based on relatively little production history and
generally are less reliable than estimates based on a longer production history.
Accordingly, reserve estimates and estimates of future net revenues from
production are likely to vary from year to year. For these and other reasons,
the price paid for purchased interests may be less than the fair market value or
initial price of such interests.
The sale of interests through the right of presentment will be a
taxable event to the selling investor partner. See "Tax Aspects - Special
Features of Oil and Gas Taxation - Sale of Interests."
ADDITIONAL FINANCING
General. The actual costs of the proposed drilling activities of a
drilling program may exceed the estimated costs of such activities and it is
possible that additional funds in addition to the initial contributions from the
participants in that drilling program may be required to complete such drilling
activities, to further develop the drilling program's oil and gas leases and to
pay for other drilling program operations. The partnership agreement does not
provide for any additional assessments, either mandatory or voluntary of any
general and limited partners. Thus, it is anticipated that a partnership's share
of such additional expenditures will be financed by partnership borrowings,
partnership revenues or the proceeds of sale of partnership properties. There
can be no assurance that such additional funds can be obtained, and if they
cannot be obtained a partnership might have to forego further drilling
activities or development of the related drilling program's oil and gas leases.
Also, the terms of oil and gas leases may bind the participants in the drilling
program to a specified drilling schedule and the inability of a partnership to
fund on a timely basis its portion of the cost of such additional specified
drilling could result in the forfeiture of a partnership's interest in such oil
and gas leases. Further, the inability to finance additional activities could
result in the sale of undeveloped acreage or farmouts to independent parties or
to affiliates of the managing partner including affiliated programs, under which
circumstances a partnership may not realize the full value of its properties.
Limitation on Borrowings. The partnership agreement authorizes the
managing partner to borrow money on behalf of a partnership and to mortgage or
pledge a partnership's property, including production from such property, as
security and to engage in any other method of financing customary in the oil and
gas industry. The sum of outstanding borrowings by a partnership may not at any
time exceed 20% of the aggregate capital contributions to the partnership. The
partnership agreement permits borrowing to finance partnership operations,
including without limitation drilling and completion activities. A partnership
may borrow funds only if the lender agrees that it will have no recourse against
the individual general and limited partners. Borrowings may be secured by a
partnership's assets or income and may be made with or without recourse to the
managing partner. The managing partner contemplates, however, that any borrowing
by a partnership will be incurred without recourse to the managing
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partner and will be secured by the partnership's property. The managing partner
does not presently intend to guarantee nonrecourse loans by third parties to a
partnership. A partnership's ability to borrow will depend in large part upon
the success of its drilling activities. There is no assurance that the managing
partner will be able to secure nonrecourse financing in an amount sufficient to
conduct drilling operations if such financing is sought, that any such financing
can be secured without the guarantee of the managing partner or an affiliate of
the managing partner or that financing can be obtained at satisfactory interest
rates or terms. A partnership's borrowings will be repaid from the partnership
revenues allocable to the partners, reducing the amounts available for
distribution to them and creating the risk that an investor partner's share of a
partnership's taxable income may be greater than the amounts distributed to him.
See "Tax Aspects -- Partnership Taxation -- General."
The partnership agreement further authorizes the managing partner and
its affiliates to make loans to a partnership for purposes permitted by the
partnership agreement. Interest charged by the managing partner or the affiliate
of the managing partner on advances made by the managing partner or such
affiliate to a partnership will be at a rate not in excess of the lesser of the
effective rate then being paid by the managing partner or the affiliate for
similar type borrowings or the highest lawful rate, and in no event at a rate in
excess of the amount which would be charged to the partnership by independent
third parties for the same purpose. The managing partner or an affiliate of the
managing partner may not receive points or other financing charges or fees on
advances made by it to a partnership. In addition, a partnership may not make
loans to the managing partner or any affiliate of the managing partner. The
managing partner may pledge its interest in a partnership but may not pledge
partnership assets for its own benefit. The managing partner however, may pledge
its directly owned interest in drilling program properties at any time and may
sell its working interests in drilling program properties pursuant to the
drilling program agreement after the cessation of substantially all drilling
activities of such drilling program.
PLAN OF DISTRIBUTION
Subscription for interests will be solicited by soliciting dealers that
are members of the National Association of Securities Dealers, Inc. on a
"minimum/maximum best efforts" basis. The soliciting dealers must sell the
minimum number of interests offered ($1,000,000) if any interests are sold and
are required to use only their best efforts to sell the maximum number of
securities offered ($10,000,000). Mewbourne Securities, Inc., an affiliate of
the managing partner, is a broker-dealer which may act as a soliciting dealer
for the partnerships. While there is no limitation on the number of interests
that may be sold by Mewbourne Securities, it is anticipated that the number of
interests, if any, sold by Mewbourne Securities will not be material.
Each soliciting dealer will receive sales commissions and due diligence
fees in an aggregate amount of up to 8.5% of the sales price of interests sold
by that soliciting dealer. No sales commissions or due diligence fees will be
paid on sales of interests to:
o officers, directors, or employees of the managing partner or its
affiliates,
o officers, directors, employees, or registered representatives of
a soliciting dealer, or
o an affiliate of the managing partner.
The total commission and fees paid to a particular soliciting dealer
may be comprised of a sales commission in an amount up to 8% of the sales price
of interests in a partnership sold by the soliciting dealer, and a due diligence
fee in an amount of up to .5% of the sales price of interests sold by the
soliciting dealer; provided that the aggregate commission and fees paid to a
soliciting dealer shall not exceed 8.5% of the sales price of interests in a
partnership sold by the soliciting dealer. The maximum compensation to be paid
to the soliciting dealers and related parties in connection with the
distribution of the offering, including, but not limited to, wholesaling
expenses, retailing expenses, sales commissions and the up to .5% in due
diligence fees will not exceed 10.5% of the aggregate gross proceeds of the
offering.
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The managing partner, under the terms of each drilling program, will
pay all organization and offering expenses, sales commissions and due diligence
fees. A portion of these fees and expenses are in the nature of wholesaling fees
and expenses. The managing partner estimates that these wholesaling fees and
expenses will be approximately $175,000 or 1.75% of the offering proceeds in the
case of the maximum offering of $10,000,000. All of these wholesaling fees and
expenses will be paid by the managing partner pursuant to the terms of the
drilling program.
The managing partner has engaged its affiliate, Mewbourne Securities,
Inc. to serve as the dealer manager for purposes of forming a soliciting dealer
group comprised of members of the National Association of Securities Dealers,
Inc. Mewbourne Securities, Inc., in its role as dealer manager and each
soliciting dealer participating in the offering of the interests may be deemed
to be an underwriter within the meaning of the Securities Act of 1933. The
managing partner and the partnerships have agreed to indemnify the soliciting
dealers, including Mewbourne Securities, Inc., against various civil
liabilities, including liabilities arising under the Securities Act of 1933.
In offering the interests, in addition to this prospectus, the managing
partner has prepared and intends to provide soliciting dealers and investors
with a brochure entitled "Mewbourne Energy Partners" concerning the offering of
the interests. Prior to the distribution, such sales materials must be filed
with and reviewed by the Securities and Exchange Commission, various state
securities administrators and by state regulatory authorities. When utilized,
such sales material must be accompanied or preceded by a prospectus. No other
sales material has been authorized by the managing partner for use in connection
with this offering. The managing partner will not offer a sales incentive
program in connection with the distribution of interests in either partnership.
INVESTMENT OBJECTIVES
Each partnership will participate in a drilling program, to be managed
by Mewbourne Oil Company in its capacity as drilling program manager, consisting
of the acquisition and development of oil and gas prospects. The primary
investment objective of each partnership is to conduct oil and gas drilling and
development activities on prospects in an attempt to establish long-life oil and
gas reserves. In addition, a drilling program's structure is intended to result
in tax benefits, consisting principally of deductions for intangible drilling
costs, depletion, and depreciation. To the extent that the operations of a
partnership and the related drilling program result in a net loss for a taxable
period, general partners will be able to claim their respective shares of the
deductions giving rise to such loss in the current year, but limited partners
will not be able to claim their shares of the deductions comprising such loss in
the current year except to the extent they have net passive income from other
sources. See "Proposed Activities" and "Tax Aspects."
PROPOSED ACTIVITIES
Under the drilling program agreement, the activities of the
partnerships will focus upon the acquisition of oil and gas leases covering
prospects, the drilling of development wells, and the production and operation
of the resulting properties. In addition to development wells, at the discretion
of the managing partner, up to 20% of a partnership's capital contributions may
be expended in connection with activities relating to exploratory wells. All
drilling activities involve a high degree of risk with exploratory wells
presenting a higher degree of risk than development wells. Mewbourne Development
Corporation will act as the managing partner of each partnership. See "Summary
of Partnership Agreement and Drilling Program Agreement -- Rights and Powers of
the Managing Partner." Mewbourne Oil Company will act, in its individual
capacity, as the drilling program manager of each drilling program and as
operator under each operating agreement.
The managing partner intends to cause the partnerships to engage in
drilling for oil and gas on a number of different prospects, none of which is
yet determined. For a number of reasons, it is impossible at this time to
predict with certainty the drilling activities that will be conducted by either
partnership. Among these reasons are that neither partnership has yet to acquire
working interests or other rights to any particular oil and gas leases and it
will do so only after the prospective offering of interests is completed.
Further, the amount of capital that will be raised by a partnership as a result
of this offering has not yet been determined. The result of the initial drilling
activities
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conducted by a partnership also may have a significant effect on the number and
location of subsequent wells. Decisions as to the management, business, and
affairs of a partnership will be made by the managing partner based upon its
judgment at the time as to the best interests of the partnership.
DEVELOPMENT POLICY
Decisions as to the number and location of the prospects in which a
partnership will invest and as to the amounts spent on drilling will be made
solely by the managing partner for the partnership and by the drilling program
manager on behalf of the related drilling program. The managing partner intends
to cause each partnership to acquire an interest in as many prospects as
practicable in order to best diversify the risks associated with drilling for
oil and gas, however, the number and type of wells to be drilled by a
partnership will vary according to the amount of funds raised, the costs of each
well and the size of the fractional working interests selected in each well.
The managing partner will designate in writing the area comprising a
prospect in which a partnership is to acquire an interest under the related
drilling program agreement at or prior to the date on which a well is spudded
(i.e., boring is commenced) on such prospect. The prospect area may be enlarged
or contracted from time to time by the managing partner on the basis of
subsequently acquired geological and engineering data to define or redefine the
productive limits of the original area of the prospect. Notwithstanding the
foregoing, with respect to any large, continuous known stratigraphic trend which
could be defined as a continuous reservoir, the managing partner, acting in good
faith, shall be permitted to limit or reduce the area of a prospect to the
minimum area permitted by state law or local practices whichever is applicable,
to protect against drainage from adjacent wells.
AREA OF GEOGRAPHIC CONCENTRATION
The managing partner anticipates that all of a partnership's funds
available for drilling activities will be expended in the Permian Basin, located
in West Texas and Southeastern New Mexico, and also the Anadarko Basin, located
in Western Oklahoma, the Texas Panhandle and Southwest Kansas. However, if the
managing partner determines that it is in the best interest of a partnership to
conduct additional drilling activities in other onshore geographic areas of the
United States, the related drilling program and the partnership may expend
available funds in such areas. At the present time, the partnerships are not
committed to any specific drilling sites. No geological, engineering or other
information about any geographic area, other than that contained in this
prospectus, will be furnished to any prospective investor and, for that reason,
no person should invest in a partnership on the basis of any expectation
regarding the results of drilling on any particular drilling location.
The Permian Basin encompasses a large area of approximately 75,000
square miles located in West Texas and Southeastern New Mexico. Since 1921, over
26 billion barrels of oil and 76 trillion cubic feet of natural gas have been
produced from the Permian Basin.
Two interior basins, the Midland Basin in West Texas and the Delaware
Basin in West Texas and Southeastern New Mexico, subdivide the Permian Basin.
Although drilling depths range from very shallow to more than 20,000 feet, the
managing partner and its affiliates target multiple Pennsylvanian and Permian
age sandstone and carbonate reservoirs along the shelf and shelf-slope areas
within the interior subbasins, which lay at depths ranging from 3,000 to 13,000
feet.
Over the past 34 years, Mewbourne Oil Company and its affiliates have
conducted operations throughout the Permian Basin. Mewbourne Oil Company
currently operates approximately 172 wells in the Permian Basin and Mewbourne
Oil Company and its affiliates have drilled approximately 168 commercially
productive oil and gas wells in the Permian Basin. These historical results are
not indicative of the results that may be achieved by the partnerships and such
results should not be used by potential investors in making an investment
decision. In addition, a commercially productive well may not necessarily have
sufficient production to recover both operating expenses and drilling and
development costs. Most current operations are centered on the shelf and along
shelf slope areas of the Delaware Basin located in Eddy, Chaves, and Lea County,
New Mexico. It is anticipated that each partnership will, through the related
drilling program, conduct a portion of its oil and gas drilling and development
activities in this area of the Permian Basin. Predominantly, wells drilled by
Mewbourne Oil Company in this region of
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the Permian Basin are classified as gas wells but produce both oil and gas.
However, Mewbourne Oil Company and its affiliates have drilled a number of wells
in this area which have been classified as oil wells.
The Anadarko Basin of Western Oklahoma, the Texas Panhandle and
Southwestern Kansas encompasses an area of approximately 60,000 square miles.
First production was established in 1917 and since that time over 6 billion
barrels of oil and 80 trillion cubic feet of natural gas have been produced from
this geological basin.
Production in the Anadarko Basin ranges from several hundred feet to
over 26,000 feet in depth. Over the past 23 years, Mewbourne Oil Company and its
affiliates have drilled approximately 344 commercially productive wells that
have targeted Pennsylvanian, Mississippian, Devonian, and Silurian age sandstone
and carbonate reservoirs along the shelf area of Western Oklahoma and the Texas
Panhandle at depths of between 6,000 and 13,000 feet. Mewbourne Oil Company
currently operates approximately 215 wells in the Anadarko Basin. It is
anticipated that each partnership will, through the related drilling program,
conduct a portion of its drilling and development activities along the shelf
area of Western Oklahoma, the Texas Panhandle and Southwest Kansas. A majority
of the wells drilled by Mewbourne Oil Company over the past 23 years in this
region of the Anadarko Basin have been classified as gas wells but produce both
oil and gas. However, Mewbourne Oil Company and its affiliates have drilled a
number of wells in this area which have been classified as oil wells.
PROSPECT EVALUATION
Mewbourne Oil Company currently employs 15 engineers, 8 geologists and
7 landmen which are available to assist in prospect origination for each
drilling program. It is anticipated that Mewbourne Oil Company, as drilling
program manager, will conduct substantially all prospect origination for each
drilling program, although a program may conduct operations on prospects
originated by third parties. Prospect origination is the process of formulating
a geological or geophysical concept and negotiating for the acquisition of a
sufficient interest in oil and gas leases covering the area to warrant drilling
and testing. Before selecting a prospect for a drilling program, the drilling
program manager will review all available engineering and geological data, which
may include, but is not limited to, logs, completion reports and plugging
reports for wells located in the vicinity of the proposed prospect.
COST ESTIMATES
Prior to conducting drilling activities on behalf of a partnership, the
managing partner will estimate the costs to be incurred by a partnership in
drilling the wells planned for the partnership. Such estimates will be based
upon the managing partner's historic experience and contracts to be entered into
by the managing partner or its affiliates and non-affiliated drilling
contractors fixing the footage drilling rates, and in limited circumstances
stimulation costs to be incurred by the partnership.
ACQUISITION OF LEASES
The decision for a partnership to acquire an interest in a prospect,
the size and nature of the interest acquired and the terms of each such
acquisition will be based upon evaluations of the properties conducted by the
managing partner after consultation with the drilling program manager or
independent geologists or engineers. To assist in conducting and interpreting
such evaluations, the managing partner or its affiliates employ a staff of
technical personnel. See "Management."
TRANSACTIONS WITH AFFILIATES
Sale of Leases to a Partnership. All oil and gas leases to be acquired
by a partnership or related drilling program will be selected by the managing
partner from a variety of prospects, substantially all of which will be
originated by the drilling program manager. The partnership agreement provides
that neither the managing partner, nor any affiliate thereof, including an
affiliated program, is permitted to sell, transfer or convey any oil and gas
lease to a partnership, directly or indirectly, except in a transaction which is
fair and reasonable to the partnership and in accordance with the following
restrictions:
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(a) The managing partner and its affiliates may only sell an oil and
gas lease to a partnership or related drilling program at a price equal to its
lease acquisition costs unless the managing partner has reasonable grounds to
believe that the lease acquisition costs is materially more than the fair market
value of the oil and gas lease. If the managing partner determines that the
lease acquisition costs is materially more than its fair market value, then,
except as described below, the oil and gas lease may not be sold to a
partnership or the related drilling program at a price that is in excess of its
fair market value. An affiliated program may sell an oil and gas lease to a
partnership or the related drilling program at its lease acquisition costs even
if its lease acquisition costs is materially more than the fair market value of
the oil and gas lease if:
o The affiliated program has held the oil and gas lease for more
than two years; and
o The economic interest of the managing partner and its affiliate
in the affiliated program is substantially similar to, or less
than, their economic interest in the drilling program.
(b) If the managing partner or its affiliate sells any oil and gas
lease within a prospect to a partnership, it must, at the same time, sell to the
partnership and the partnership must buy an equally proportionate interest in
all other oil and gas leases that it owns in the same prospect.
(c) If at any time within a period of five years from a partnership's
funding, the managing partner or its affiliate proposes to acquire an interest
from a non-affiliated person in a prospect in which the partnership possesses an
interest or in a prospect in which the partnership's interest has been
terminated without compensation within one year preceding such proposed
acquisition, the following conditions will apply:
o if the managing partner or any affiliate of the managing partner
does not currently own property in the prospect separately from
the partnership, then neither the managing partner nor any
affiliate of the managing partner will be permitted to purchase
an interest in the prospect; and
o if the managing partner or any affiliate of the managing partner
currently owns a proportionate interest in the prospect
separately from the partnership, then the interest to be acquired
will be divided between that partnership and the managing partner
or an affiliate of the managing partner in the same proportion as
is the other property in the prospect; provided, however, if cash
or financing is not available to the partnership to enable it to
consummate a purchase of the additional interest to which it is
entitled, then neither the managing partner, nor any affiliate
thereof may purchase any additional interest in the prospect
during such five year period.
(d) If the area constituting a partnership's prospect is subsequently
enlarged to encompass any area in which the managing partner or any affiliate of
the managing partner owns a separate oil and gas lease, such separate oil and
gas lease or a portion of such lease must be sold, transferred, or conveyed to
the partnership, if the activities of the partnership were material in
establishing the existence of proved undeveloped reserves that are attributable
to such oil and gas lease.
(e) A sale, transfer, or conveyance of less than all of the ownership
of the managing partner or any affiliate of the managing partner in any oil and
gas lease is prohibited unless the interest retained by the managing partner or
such affiliate is a proportionate working interest, the respective obligations
of the managing partner or such affiliate and the partnership are substantially
the same after the sale of the interest by the managing partner or such
affiliate, and its interest in revenues does not exceed the amount proportionate
to its retained working interest. Neither the managing partner, nor any
affiliate of the managing partner may retain any overriding royalty interest or
other burden on an interest conveyed to a partnership.
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(f) For the purposes of the preceding four paragraphs, the term
"affiliate" does not include an affiliated program in which the interest of the
managing partner or an affiliate of the managing partner is substantially
similar to or less than its interest in the partnership.
(g) If a partnership acquires an oil and gas lease through a farmout or
joint venture from an affiliated program, the managing partner's, and any of its
affiliate's aggregate compensation associated with the property and any direct
or indirect ownership interest in the property may not exceed the lower of the
compensation and ownership interest the managing partner and such affiliates
could receive if the property were separately owned or retained by either the
partnership or such other affiliated program.
A determination of fair market value must be supported by an appraisal
from an independent expert. Such opinion and any associated supporting
information must be maintained in the drilling program's records for at least
six years. In determining whether the lease acquisition costs is materially more
than the fair market value of a particular oil and gas lease you must rely upon
the managing partner's good faith in making the determination of materiality.
Purchase of Leases from a Partnership. Neither the managing partner nor
any affiliate of the managing partner, including affiliated programs, may
purchase or acquire any oil and gas lease from a partnership, directly or
indirectly, except in transactions that are fair and reasonable to the
partnership and then subject to the following conditions:
o A sale, transfer, or conveyance, including a farmout, of an oil
and gas lease not having any proved developed reserves
attributable to it from a partnership to the managing partner or
its affiliate, other than an affiliated program, must be made at
the higher of the lease acquisition costs or fair market value.
o A sale, transfer, or conveyance of an oil and gas lease having
proved developed reserves attributable to it from a partnership
to the managing partner or its affiliate, other than an
affiliated program in which the interest of the managing partner
or its affiliate is substantially similar to or less than its
interest in the partnership, is not permitted except in
connection with the liquidation of the partnership and then only
at fair market value.
o Except in connection with farmouts or joint ventures made in
compliance with the restrictions described in paragraph (b) above
under the heading "Sales of Leases to a Partnership," a transfer
of an undeveloped oil and gas lease from a partnership to an
affiliated program must be made at fair market value if the oil
and gas lease has been held for more than two years; otherwise,
if the managing partner deems it to be in the best interest of
the partnership, the transfer may be made at the lease
acquisition costs.
o Except in connection with farmouts or joint ventures made in
compliance with the restrictions described in paragraph (b) above
under the heading "Sales of Leases to a Partnership," a transfer
of any oil and gas lease from a partnership to an affiliated
program, whose investment objective is to directly acquire, hold,
operate and/or dispose of producing oil and gas properties, must
be made at fair market value if the oil and gas lease has been
held for more than six months or there have been significant
expenditures made in connection with the oil and gas lease;
otherwise, if the managing partner deems it to be in the best
interest of the partnership, the transfer may be made at the
lease acquisition costs as adjusted for intervening operations.
A determination of fair market value must be supported by an appraisal
from an independent expert. Such opinion and any associated supporting
information must be maintained in the drilling program's records for at least
six years.
Participation by Mr. Mewbourne. Mr. Mewbourne has historically invested
directly or indirectly in the drilling and development activities of Mewbourne
Oil Company and its affiliates during the past 34 years. In
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addition he has been an investor in the joint ventures and drilling agreements
through which other investors participated in various Mewbourne Oil Company
managed programs. Mr. Mewbourne's annual participation varied considerably both
in level of investment and form, but in general approximated 25% to 50% of the
annual expenditures.
Mr. Mewbourne and/or affiliates intend to invest alongside each
partnership in the activities of the related drilling program, however, there is
no assurance that the amount of Mr. Mewbourne's participation will be in
accordance with his historical custom. The amount of such investment will be
subject to many variables, including the availability of working interests in
the oil and gas leases, the amount of capital available to the partnerships from
subscriptions, the timing of the drilling activities, and other such matters.
FARMOUTS
A partnership will acquire only those oil and gas leases that are
reasonably required for the stated purpose of the partnership, and no oil and
gas leases will be acquired for the purpose of subsequent sale or farmout,
unless the acquisition of such oil and gas leases by the partnership is made
after a well has been drilled to a depth sufficient to indicate that such an
acquisition is believed to be in the best interests of the partnership.
The necessity to enter into farmouts is most likely to occur when a
partnership has insufficient funds to bear development costs accompanying an oil
and gas lease or where the development costs or attendant risks are substantial.
The managing partner may arrange for the development or disposition of a
partnership's oil and gas leases by farmout arrangements with third parties or
affiliates, including an Affiliated Program, if the managing partner, in
exercising the standard of a prudent operator, determines that:
o a partnership lacks sufficient funds to drill on the oil and gas
leases and cannot obtain suitable alternative financing for such
drilling,
o the oil and gas leases have been downgraded by events occurring
subsequent to their acquisition by that partnership so that the
drilling of the oil and gas leases would no longer be desirable
to the partnership,
o drilling on the oil and gas leases would result in an excessive
concentration of a partnership's funds in one location creating,
in the opinion of the managing partner, undue risk to the
partnership, or
o the best interests of a partnership would be served by the
farmout.
A partnership will not farmout an oil and gas lease for the primary
purpose of avoiding payment of its costs related to drilling such oil and gas
lease or prospect.
A partnership may also farmin oil and gas leases from third parties or
its affiliates, including affiliated programs, in partial or in full
consideration for its agreement to drill one or more wells thereon.
Any farmouts between a partnership and the managing partner or an
affiliate of the managing partner will be on terms substantially consistent
with, in the opinion of the managing partner, those available from
non-affiliated third parties in the same geographic area for similar
arrangements. No farmout shall be entered into between a partnership and the
managing partner or an affiliate of the managing partner unless the managing
partner, exercising the standard of a prudent operator, shall determine that the
farmout is in the best interests of that partnership and the general and limited
partners. A partnership's authority to enter into farmouts with the managing
partner or an affiliate of the managing partner is subject to the same
restrictions as its authority to purchase property from or sell property to the
managing partner or an affiliate. See "-- Transactions with Affiliates" above.
For a discussion of the prudent operator standard of conduct, see "Conflicts of
Interest -- Fiduciary Responsibility of the Managing Partner."
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Any decision with respect to farmouts and farmins and the terms of any
such farmout or farmin to or from a drilling program will involve conflicts of
interest, as the managing partner may benefit from cost savings and reduction of
risk, and in the event of a farmout or farmin to or from an Affiliated Program,
the managing partner will represent both programs involved in the transaction.
See "Conflicts of Interest."
For a discussion of federal income tax risks and considerations
associated with farmouts, see "Tax Aspects -- Special Features of Oil and Gas
Taxation -- Farmouts and Backin Interests."
OPERATIONS
All administration of each drilling program, including the origination
of prospects and the supervision of drilling and completion activities with
respect to those operations for which it is acting as operator, will be
conducted by Mewbourne Oil Company in its capacity as the drilling program
manager. All management functions of a partnership will be conducted by
Mewbourne Development Corporation in its capacity as managing partner. The
drilling program manager will perform all operating services relating to program
wells, and will be entitled to be reimbursed for such services in an amount
equal to all charges, including certain overhead charges, which constitute
direct and indirect charges under the operating agreement or other applicable
operating agreements incurred by the drilling program manager in connection with
drilling or operating a program well, including an initial fixed rate,
per-month, overhead charge of $780 for each producing well and $7,420 for each
drilling well. The amount of the fixed rate overhead charges have been
determined based upon:
o The anticipation that each partnership's activities will be
conducted in the Permian Basin, located in West Texas and
Southeastern New Mexico and also the Anadarko Basin, located in
Western Oklahoma, the Texas Panhandle and Southwest Kansas;
o The managing partner's estimate of the current fixed rate
overhead charges charged by other non-affiliated operators in the
anticipated area of operations; and
o guidelines set by the Council of Petroleum Accountants Societies
of North America.
The drilling program manager and affiliates of the drilling program
manager currently employ approximately 103 persons on a full time basis, many of
whom will be engaged in some aspect of a drilling program's activities. In
addition to its own employees, the drilling program manager may utilize the
services of consultants for well drilling and completion activities, production
accounting and other activities. The managing partner currently employs 3
persons, all of whom are members of the drilling program manager's executive
management group.
Under the drilling program agreement, the drilling program manager has
agreed to act as operator with respect to drilling and production operations
conducted on each program well, except in those instances in which:
o the oil and gas lease on which such program well is to be drilled
is already subject to an existing operating agreement under which
a third party has been designated as operator,
o the requisite number of third parties being joint working
interest owners in such well elect another entity as operator, or
o the drilling program manager determines in good faith that it is
not in the best interests of the participants in the drilling
program and of the drilling program manager for it to act as
operator.
In any case in which the drilling program manager or its affiliate acts
as operator for a drilling program's properties or provides other services or
materials to a drilling program, it will do so only under a written agreement
and only on terms and conditions comparable to those entered into by
non-affiliated parties in the same area. Any such agreement will precisely
describe the services to be rendered and all compensation to be paid and will
require a partnership and its partners to pay only that portion of the fees
allocable to their working interest. Fees received by
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the drilling program manager or its affiliate under any such operating agreement
may constitute additional compensation. See "Compensation and Reimbursement."
With respect to each program well for which the drilling program
manager is to serve as operator, all operations relating to the program well,
including without limitation, all costs and expenditures of drilling, testing,
completing, equipping, and operating the program well shall be conducted under
an operating agreement between the drilling program manager as operator, and the
participants in the drilling program as non-operator, with the operating
agreement to be substantially in the form and substance as the operating
agreement attached to this prospectus as Attachment B to the drilling program
agreement. In the event, at the time of acquisition of an oil and gas lease by
the drilling program, such oil and gas lease is subject to another operating
agreement or if the drilling program manager enters into an operating agreement
with third parties being joint working owners in such program well,
nevertheless, the operating agreement between the drilling program manager and
the participants in the drilling program shall govern operations as between
them. However, the drilling program manager and the managing partner shall have
the right to amend the operating agreement between the drilling program manager
and the participants in the drilling program covering specified oil and gas
leases in order to conform to such other operating agreement, except that the
operating agreement may not be amended in any manner that the managing partner
determines will adversely affect a partnership or the general and limited
partners in any material respect. The drilling program manager shall have the
right to charge the joint account under the operating agreement between the
drilling program manager and the participants in the drilling program a share
attributable to the participants' working interest of any costs or expenses
incurred by the drilling program manager under such other operating agreement
which are not otherwise provided for in the drilling program agreement or in the
operating agreement between the drilling program manager and the participants in
the drilling program.
TITLE TO PARTNERSHIP PROPERTIES
Program wells will be drilled on oil and gas leases having limited
warranties of title, or none at all. As is customary in the oil and gas
industry, the only investigation of title made at the time of acquisition of
undeveloped properties is a preliminary review of local real estate records.
Prior to drilling a program well on a prospect, the drilling program manager
shall cause to be done or be satisfied that there has been done such title
examination and other title curative work as the drilling program manager in its
sole discretion, shall determine to be necessary or appropriate in accordance
with general industry standards. In addition, a drilling title opinion is
generally secured before commencement of drilling operations. Title to a
partnership's properties will be held temporarily in the name of the drilling
program manager in the capacity of nominee, with record title being transferred
to a partnership following commencement of production from a program well. In
certain circumstances a partnership will not receive record title. These
circumstances include without limitation:
o where record title is held in the name of a third party, as in
the case where it is industry practice that, record title is held
by a third party, such as a pooled operating interest, or
o in the case of a federal, state, or other oil and gas lease,
where an approval to the transfer is required.
In cases where approval of a third party is required in order to
transfer a working interest in an oil and gas lease, the drilling program
manager will take steps to obtain approval of appropriate third parties to the
assignment to the participants in the drilling program as promptly as possible.
INSURANCE
The managing partner expects to conduct the business of each
partnership and to cause the drilling program manager to conduct the business of
each drilling program in a manner intended to limit, to the extent practicable,
the exposure of the general partners to liability in excess of their capital
contributions to that partnership. See "Liability of General and Limited
Partners -- General Partners" for a discussion of the potential liability of
general partners. It is anticipated that drilling activities of the partnerships
will be conducted in the medium depths between 3,000 to 13,000 feet of the
Northwest Shelf, and the shelf of the Delaware and Midland Basins, and Central
Basin Platform geological sub-regions of the Permian Basin and the shelf and the
shelf slope area of the Anadarko Basin where the
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probability of encountering severely over-pressured formations and other hazards
associated with drilling activities is less likely. The drilling program manager
and its affiliates will maintain extensive insurance coverage to protect, to the
extent practicable, each partnership from losses that could arise in connection
with program activities, including legal and contractual liability to third
parties.
The drilling program manager and its affiliates expect to retain the
insurance coverage described below, unless such coverage becomes unobtainable or
is only available at premiums which are prohibitively more expensive than the
premiums now being paid for such policies. However, the drilling program manager
and its affiliates will not be required to retain operator's extra expense and
care, custody and control insurance coverage for a partnership after the related
drilling program has completed its drilling activities.
A brief discussion of the insurance policies that the drilling program
manager and its affiliates have obtained on behalf of themselves and the
partnerships is set forth below. Each of those policies is subject to terms,
conditions, exclusions, and limitations that may preclude a partnership from
recovering damages, expenses, and liabilities suffered by that partnership,
including typically, damages and liabilities arising from or caused by:
o the violation of any federal, state, or local statute, ordinance,
or regulation,
o fines, penalties, and punitive and exemplary damages,
o war and terrorist acts,
o normal operation including wear and tear,
o faulty design, and
o the fraud, disloyalty, theft, malicious acts or other similar
conduct of employees.
Other exclusions that are customary in the insurance and oil and gas industries
may also apply, including exclusions relating to pollution and environmental
damages. The drilling program manager believes that from time to time the terms,
conditions, exclusions, and limitations described in this section of the
prospectus may prevent a partnership from recovering the full amount of any
damages, expenses, and liabilities suffered by the partnership which arise in
the event of an accident. In some cases a partnership may not recover any
portion of such damages, expenses, and liabilities.
If the drilling program manager and its affiliates cease to retain the
coverage described below for any reason for a period of more than 20 days during
the subscription period for a partnership, the offering of interests in that
partnership shall cease, and subscribers for interests who have not been
admitted as general and limited partners in the partnership shall receive a
refund of their subscription funds. The managing partner will notify general and
limited partners of any material reduction in the insurance coverage of a
drilling program and partnership. Such notice shall be given thirty days in
advance of the change in insurance coverage. In addition, if a drilling program
or a partnership has its insurance coverage materially reduced for any reason,
the partnership will halt all drilling activity until such time as comparable
replacement coverage is obtained.
The drilling program manager and its affiliates maintain comprehensive
general liability, employers liability, and commercial automobile insurance
policies that generally protect the insured against the routine hazards
encountered by the drilling program manager, its affiliates and its employees
and agents in the conduct of the business of the drilling program manager and
its affiliates. The coverage amount under each of these policies is limited to
$1,000,000 per occurrence. In addition, the drilling program manager and its
affiliates maintain a comprehensive energy package and an excess liability
policy that together provide an additional coverage amount of $50,000,000 per
occurrence. The comprehensive energy package and excess liability policy are in
effect and are renewed annually, but may be canceled by the insurance
underwriters upon a minimum of 60 days written notice.
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The physical damage section of the comprehensive energy package, which
has a coverage limit of $5,000,000 per occurrence, generally protects the
insured against all risks of direct physical loss or damage to all personal
property, except drilling rigs and related equipment, vehicles, oil and gas, and
various other personal property, for which the insured has liability or is
legally liable, subject to a maximum deductible of $5,000 per occurrence or
$25,000 in the case of earthquake.
The operators extra expense/seepage and pollution section of the
comprehensive energy package, which has a coverage limit of $3,000,000 for land
wells less than 10,000 feet in depth and a limit of $10,000,000 for wells
greater than 10,000 feet in depth, generally protects the insured from:
o the costs to regain control of a well that goes out of control,
costs to redrill or restore a well which has been lost or
otherwise damaged as a result of an out of control well,
o third party claims for property damage relating to seepage,
pollution, or contamination arising from a well out of control
and the cost of cleaning up such substances,
o loss, damage, or expense arising from the uncontrollable flow of
oil, gas, or water from one subterranean stratum to another
through the bore of a well, and
o evacuation expense if ordered by a governmental agency.
The excess umbrella liability policies, which have coverage limits of
$50,000,000, generally protect the insured against all liabilities imposed upon
an insured by law or assumed under contract or agreement by the insured for
damages on account of personal injuries, property damage, or advertising
liability such as libel, slander, defamation and invasion of privacy caused by
or arising out of an occurrence happening anywhere in the world. Injury and
damage arising from seepage, pollution, or contamination is covered only if
caused by a sudden, unintended, and unexpected happening. Injury and damage
arising from pollution is not covered for sites used in handling, processing,
treatment, storage, or disposal of waste substances or the transportation of
waste substances.
THE MANAGING PARTNER'S POLICY REGARDING ROLL-UP TRANSACTIONS
Although the managing partner has no intention of causing either
partnership to engage in a roll-up transaction, it is possible at some
indeterminate time in the future that a partnership will become so involved. A
roll-up means a transaction involving the acquisition, merger, conversion, or
consolidation, either directly or indirectly, of a partnership and the issuance
of securities by the "roll-up entity." The term "roll-up" does not include a
transaction involving the conversion to corporate, trust, or association form of
only a partnership if, as the consequence of the transaction, there will be no
significant adverse change in any of the following:
o voting rights,
o the term of existence of the entity (formerly the partnership),
o compensation to the managing partner and its affiliates, or
o the entity's investment objectives.
For the purposes of the foregoing, a "roll-up entity" means a
partnership, trust, corporation, or other entity that would be created or
survive after the successful completion of a proposed roll-up transaction. In
the case of transactions excluded from the definition of a roll-up, the
additional protections for general and limited partners described below would
not be available to the general and limited partners. For the purposes of
determining whether or not a transaction constituted a roll-up, the managing
partner would make the determination as to whether or not there would be no
"significant adverse change" in voting rights, the term of existence,
compensation, or investment objectives. The managing partner realizes that to
some extent the determination of whether or not such a change would be
"significant" or "adverse" may vary from investor partner to investor partner.
Accordingly, the managing
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partner intends to interpret the terms "significant" and "adverse" broadly if it
is ever called upon to do so and will use its best efforts to interpret those
terms as to their applicability to any reasonable investor partner, and not only
as to what it perceives to be the circumstances of a majority of the general and
limited partners.
The partnership agreement provides various policies in the event that a
roll-up should occur in the future. These policies include:
o An appraisal of all partnership assets will be obtained from a
competent Independent Expert, and a summary of the appraisal will
be included in a report to the general and limited partners in
connection with a proposed roll-up.
o Any investor partner who votes "no" on the roll-up proposal would
be offered a choice of:
-- accepting the securities of the roll-up entity offered in
the proposed roll-up, or
-- either (a) remaining a limited partner or general partner in
the partnership and preserving his or her interest in that
partnership on the same terms and conditions as existed
previously, or (b) receiving cash in an amount equal to his
or her pro-rata share of the appraised value of the net
assets of that partnership.
o A partnership will not participate in a proposed roll-up:
-- which would result in the diminishment of the general and
limited partners' voting rights in the partnership agreement
under the roll-up entity's organizational documents,
-- which includes provisions which would operate to materially
impede or frustrate the accumulation of shares by any
purchaser of the securities of the roll-up entity, except to
the minimum extent necessary to preserve the tax status of
the roll-up entity,
-- which would limit the ability of an investor partner to
exercise the voting rights of its securities in the roll-up
entity on the basis of the number of roll-up entity
interests held by such investor partner,
-- in which the participants' rights of access to the records
of the roll-up entity would be less than those provided in
the partnership agreement, or
-- in which any of the costs of the transaction would be borne
by a partnership if the proposed roll-up were not approved
by the general and limited partners.
o Any roll-up transaction involving a partnership requires the
approval of a at least 66% of the total interests held by the
general and limited partners.
Depending upon the structure of any possible roll-up which may present
itself, it is possible that remaining a limited partner or an general partner in
the related partnership on the same terms and conditions as existed prior to the
roll-up may not be possible. In such a situation, the managing partner would be
required to either not consummate the proposed Roll-Up if any investor partner
votes "no" or offer the general and limited partners the option of receiving
cash in an amount equal to his or her pro-rata share of the appraised value of
the net assets of the partnership.
General and limited partners should understand that the selection of a
cash payment in an amount equal to an their pro-rata share of the appraised
value of the net assets of a partnership may not fully compensate the investor
partner for his investment.
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MANAGEMENT
Mewbourne Development Corporation was originally incorporated in 1982
as Caliche Pipeline Company in the state of Texas. The company was formed to
facilitate the gathering, transporting and marketing of natural gas. In 1990,
Caliche Pipeline Company was merged into a newly incorporated Caliche Pipeline
Company, a Delaware corporation. In 1992, Caliche Pipeline Company sold all its
remaining interest in gas gathering and marketing activities to an affiliated
company, and changed its name to Mewbourne Development Corporation. Mewbourne
Development Corporation will serve as the managing partner of each partnership
and in such capacity will have the sole power and authority to act on behalf of
the partnerships with respect to the management, control, and administration of
the properties, business, and affairs of each partnership. The managing partner
was organized for the purpose, among other things, of engaging in any and all
phases of the oil and gas business, including sponsoring and forming limited or
general partnerships for the purpose of acquiring and owning working interests
in oil and gas properties and offering limited or general partner interests
therein to investors.
Mewbourne Oil Company, a Delaware corporation, was incorporated in 1967
and is a wholly owned indirect subsidiary of Mewbourne Holdings, Inc. The
drilling program manager provides management and technical services and serves
as operator for ventures of Mewbourne Holdings, Inc., the managing partner and
Mr. Mewbourne. In this connection, the drilling program manager develops oil and
gas prospects, acquires leasehold interests, and serves as the operator in the
drilling, completion, and production of oil and gas wells. Mewbourne Oil Company
will also conduct the administration of the business, and affairs of each
drilling program. Mewbourne Oil Company maintains offices in Tyler, Perryton,
Midland and Amarillo, Texas; Hobbs, New Mexico; and Oklahoma City and Woodward,
Oklahoma. The general offices are located at 3901 South Broadway, Tyler, Texas
75701. Mewbourne Oil Company employs approximately 103 persons including 15
engineers, 9 geologists, 7 landmen, 8 accountants, and 12 other degreed
administrative professionals.
Mewbourne Holdings, Inc., a Texas corporation, was founded by Mr.
Mewbourne in 1965 and is a privately owned corporation which serves as the
parent company for both the managing partner and the drilling program manager
and their affiliates.
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OWNERSHIP STRUCTURE OF MEWBOURNE COMPANIES
Corporate Structure
--------------------------
Mewbourne Holdings, Inc. ---------------
-------------------------- -
- -
-------------------------- -
Mewbourne -
Financial ----------------------
Corporation Mewbourne
-------------------------- Development
- Corporation,
- Managing General
-------------------------- partner
Mewbourne Oil ----------------------
Company, -
-
Operator/Program Mgr. -
-------------------------- ----------------------
Mewbourne -
-------------------------- Energy - INVESTORS
partners 99-00 -
----------------------
-------------------- -
Curtis W. -------------------------- -
Mewbourne ------- -
or affiliates -------------
-------------------- Program Wells
--------------------
Mewbourne -------
Operated Joint --------------------------
Ventures
or partnerships
--------------------
Both the managing partner and the drilling program manager are directly or
indirectly wholly owned subsidiaries of Mewbourne Holdings, Inc. The following
table provides information as to the beneficial ownership of Mewbourne Holdings,
Inc., as of December 31, 1999 by each person who, to their knowledge,
beneficially owned 5% or more of their respective outstanding capital stock.
Number and
Class of percent of Percent of
Owner Security Share Voting Rights
----- --------------- ------------- -------------
Curtis W. Mewbourne Preferred stock 24,000 shares 92%
$.10 par value 100%
Ruth Anne Mewbourne and Julie Mewbourne Common stock 700 shares 2.6666%
Trustees of the Dorothy Elizabeth Mewbourne $.10 par value 33.33%
Trust No. 1
Dorothy Elizabeth Mewbourne and Julie Common stock 700 shares 2.6666%
Mewbourne, Trustees of the Ruth Anne $.10 par value 33.33%
Mewbourne Trust No. 1
Dorothy Elizabeth Mewbourne and Ruth Anne Common Stock 700 shares 2.6666%
Mewbourne, Trustees of the Julie Mewbourne $.10 par value 33.33%
Trust No. 1
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OFFICERS, DIRECTORS AND KEY EMPLOYEES OF THE MANAGING PARTNER AND THE DRILLING
PROGRAM MANAGER
Set forth below are the names, ages and positions of the officers,
directors and key employees of the managing partner and the drilling program
manager. Directors are elected to serve until the next annual meeting of
shareholders or until their successors are elected and qualified, and officers
serve at the discretion of the Board of Directors.
Officers and Directors of the Managing Partner
Name Position
---- --------
Curtis W. Mewbourne.................................................. President and Director
J. Roe Buckley....................................................... Treasurer, Chief Financial Officer and
Secretary
Michael F. Shepard .................................................. Secretary and General Counsel
Dorothy M. Cuenod.................................................... Assistant Secretary and Director
Ruth M. Buckley...................................................... Assistant Secretary and Director
Julie M. Greene...................................................... Assistant Secretary and Director
Officers and Directors of the Drilling Program Manager
Name Position
---- --------
Curtis W. Mewbourne.................................................. President and Director
Joseph F. Odom....................................................... Vice President of Administration and
Personnel
J. Roe Buckley....................................................... Vice President, Treasurer, Chief Financial
Officer and Secretary
Dorothy M. Cuenod.................................................... Assistant Secretary and Director
Monty L. Whetstone................................................... Vice President-Production
Kenneth S. Waits..................................................... Vice President-Exploration
Ruth M. Buckley...................................................... Assistant Secretary and Director
Julie M. Greene...................................................... Assistant Secretary and Director
Curtis W. Mewbourne, age 64, formed Mewbourne Holdings, Inc. in 1965
and serves as Chairman of the Board and President of Mewbourne Holdings, Inc.,
Mewbourne Oil Company and Mewbourne Development Corporation. He has operated as
an independent oil and gas producer for the past 35 years. Mr. Mewbourne
received a Bachelor of Science Degree in Petroleum Engineering from the
University of Oklahoma in 1957. Mr. Mewbourne is the father of Dorothy M.
Cuenod, Ruth M. Buckley, and Julie M. Greene and the father-in-law of J. Roe
Buckley.
Joseph F. Odom, age 61, joined Mewbourne Oil Company as Manager,
Administration and Personnel of Mewbourne Oil Company in November, 1981, and was
elected Vice President of Administration and Personnel in March, 1993. Prior to
joining Mewbourne Oil Company, Mr. Odom was employed in personnel management
positions with Delta Drilling Company from 1980 to 1981, with Great Lakes
Chemicals from 1978 to 1980 and with Air Products and Chemicals from 1963 to
1978. Mr. Odom received a Bachelor of Science in Management from the University
of West Florida.
J. Roe Buckley, age 37, joined Mewbourne Holdings, Inc. in July, 1990
and serves as Vice President, Treasurer, Chief Financial Officer and Secretary
of both Mewbourne Development Corporation and Mewbourne Oil Company. Mr. Buckley
was employed by Mbank Dallas from 1985-1990 where he served as a commercial loan
officer. He received a Bachelor of Arts in Economics from Sewanee in 1984. Mr.
Buckley is the son-in-law of Curtis W. Mewbourne and is married to Ruth M.
Buckley. He is also the brother-in-law of Dorothy M. Cuenod and Julie M. Greene.
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Michael F. Shepard, age 53, joined Mewbourne Oil Company in 1986 and
serves as Secretary and General Counsel of Mewbourne Development Corporation. He
has practiced law exclusively in the oil and gas industry since 1979 and
formerly was counsel with Parker Drilling Company and its Perry Gas subsidiary
for seven years. Mr. Shepard holds the Juris Doctor degree from the University
of Tulsa where he received the National Energy Law and Policy Institute award as
the outstanding graduate in the Energy Law curriculum. He received the B.A.
degree, magna cum laude, from the University of Massachusetts in 1976. Mr.
Shepard is a member of the bar in Texas and Oklahoma.
Dorothy Mewbourne Cuenod, age 40, received a B.A. Degree in Art History
from the University of Texas and a Masters of Business Administration Degree
from Southern Methodist University. Since 1984 she has served as a Director and
Assistant Secretary of both Mewbourne Development Corporation and Mewbourne Oil
Company. Ms. Cuenod is the daughter of Curtis W. Mewbourne and is the sister of
Ruth M. Buckley and Julie M. Greene. She is also the sister-in-law of J. Roe
Buckley.
Ruth Mewbourne Buckley, age 38, received a Bachelor of Science Degrees
in both Engineering and Geology from Vanderbilt University. Since 1987 she has
served as a Director and Assistant Secretary of both Mewbourne Development
Corporation and Mewbourne Oil Company. Ms. Buckley is the daughter of Curtis W.
Mewbourne and is the sister of Dorothy M. Cuenod and Julie M. Greene. She is
also the wife of J. Roe Buckley.
Julie Mewbourne Greene, age 36, received a B.A. in Business
Administration from the University of Oklahoma. Since 1988 she has served as a
Director and Assistant Secretary of both Mewbourne Development Corporation and
Mewbourne Oil Company. Prior to that time she was employed by Rauscher, Pierce,
Refsnes, Inc. Ms. Greene is the daughter of Curtis W. Mewbourne and is the
sister of Dorothy M. Cuenod and Ruth M. Buckley. She is also the sister-in-law
of J. Roe Buckley.
KEY EMPLOYEES
J. Allen Brinson - Mr. Brinson, age 49, Administrative Land Manager and
Assistant Secretary, has been with Mewbourne Oil Company since January, 1979.
Previously, he was employed for two years by Gulf Oil Corporation in its Land
Department. Mr. Brinson received a Bachelor of Business Administration from
Angelo State University in 1973 and a Master of Business Administration from the
University of Texas-Permian Basin in 1977.
B. Alan Clark - Mr. Clark, age 47, Controller and drilling program
Administrator, joined Mewbourne Oil Company May, 1979. Prior to joining
Mewbourne Oil Company, Mr. Clark was employed by Texas Oil and Gas Corporation
as Assistant Supervisor of Joint interest Accounting from 1976 to 1979. Mr.
Clark has served in several accounting/financial positions with Mewbourne Oil
Company prior to his current position. Mr. Clark received a Bachelor of Business
Administration in Accounting from the University of Texas at Arlington.
W. Ronald Howell - Mr. Howell, age 47, District Manager-Woodward,
Oklahoma District, joined Mewbourne Oil Company in July, 1979. Previously, he
was employed by AMOCO Production Company in production assignments. Mr. Howell
received a Bachelor of Science in Engineering from Texas Tech University in
1975.
A. Wayne Jones - Mr. Jones, age 44, Manager-Oil and Gas Marketing,
joined Mewbourne Oil Company in April, 1984. He was previously employed by
Crystal Oil Company as Manager of Natural Gas Sales Administration. Mr. Jones
received a Bachelor of Business Administration in 1978 and a Master of Business
Administration in Marketing in 1980 from Louisiana Tech University.
Bryan M. Montgomery - Mr. Montgomery, age 40, Manager-Economics and
Evaluation, joined Mewbourne Oil Company upon his graduation from the University
of Oklahoma in August, 1984, where he received a Bachelor of Science in
Petroleum Engineering. Mr. Montgomery has previously served in operations and
reservoir engineering positions.
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Ralph P. Moore - Mr. Moore, age 49, District Exploration Manager,
joined Mewbourne Oil Company in August, 1993 as a prospect geologist. After
graduating from Stephen F. Austin State University in 1972 with a Bachelor of
Science in Geology, Mr. Moore served in various positions in the oil and gas
industry. Prior to joining Mewbourne Oil Company, Mr. Moore served as Regional
Exploration Manager for Pacific Enterprises Oil Company.
Roy L. Hunter - Mr. Hunter, age 52, has been with Mewbourne Oil Company
since January 1998 and is District Manager Exploration office-Amarillo, Texas.
He graduated from the University of Texas at Austin with a B.A. in 1972. For the
five years prior to joining MOC, Mr. Hunter was a Division Land Manager with
Maxus Energy Corporation.
Jarold W. Elgin - Mr. Elgin, age 40, District Manager-Hobbs, New
Mexico, joined Mewbourne Oil Company in February, 1998. After graduating from
Mississippi State in 1983 with a Bachelor of Science in Petroleum Engineering,
Mr. Elgin worked as the Operations Manager of the Blackbird Company, a Louisiana
independent oil and gas company, from 1988 to 1998. He joined Mewbourne from the
Blackbird Company.
Tony D. Phillips - Mr. Phillips, age 42, District Exploration Manager
for Oklahoma City, joined Mewbourne Oil Company in August, 1980 upon his
graduation from the University of Oklahoma where he received a Bachelor of
Science in Petroleum Land Management. Previously, Mr. Phillips has served as
Landman and District Landman. Mr. Phillips manages exploration efforts in the
Anadarko Basin in Western Oklahoma.
Brent R. Thurman - Mr. Thurman, age 40, District Manager-Perryton,
Texas District, joined Mewbourne Oil Company in January 1983. Prior to his
present assignment, he served in various supervisory positions in production and
completions at both Hobbs, New Mexico and Perryton, Texas. Mr. Thurman received
a Bachelor of Science in Petroleum Engineering from Texas Tech University in
1982.
Kenneth S. Waits - Mr. Waits, age 39, Vice President of Exploration,
has been with Mewbourne Oil Company since February, 1984. He joined the company
following his graduation from the University of Oklahoma where he received a
Bachelor of Science in Petroleum Engineering in December, 1983. He currently
manages all of Mewbourne Oil Company's exploration efforts. He has also served
as Exploration Manager for Western Oklahoma. Previously, he held positions in
Operations and in Reservoir/Evaluations.
Monty L. Whetstone - Mr. Whetstone, age 38, Vice President of
Production, joined Mewbourne Oil Company in June, 1985 after graduating from
Texas Tech University with a Bachelor of Science in Petroleum Engineering. Mr.
Whetstone served as a District Superintendent - Woodard, Oklahoma, Unit Engineer
and as the Drilling/Production Engineering Supervisor prior to assuming his
present position.
COMPENSATION
None of the officers or directors of the managing partner or the
drilling program manager will receive remuneration directly from the
partnerships or the drilling programs, but will continue to be compensated by
their present employers. Each partnership and each drilling program will
reimburse the managing partner, the drilling program manager, and their
affiliates for costs of overhead falling within the definition of administrative
costs, including without limitation, salaries of the officers and employees of
the managing partner or drilling program manager; provided that no portion of
the salaries of the directors or of the executive officer of the managing
partner or drilling program manager may be reimbursed as administrative costs.
EXECUTIVE OFFICER
Mr. Mewbourne directly controls and directs all key policy decisions of
the management group of the managing partner and the drilling program manager
and is the only executive officer of both the managing partner and the drilling
program manager.
Cash Compensation to Executive Officer. The cash compensation paid by
the managing partner and the drilling program manager for services rendered
during the year ended December 31, 1999 to Mr. Mewbourne was
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$124,800. As of the date of this prospectus, members of the respective boards of
directors of the managing partner and the drilling program manager do not
receive any special compensation for serving as director.
Executive Officer Compensation Under Plans. Mewbourne Oil Company
maintains the Employees' Pension Plan and Trust as a qualified defined benefits
plan for all full time employees with five years of service. The Employees'
Pension Plan and Trust provides for maximum retirement benefits of 50% of an
employee's average monthly base pay, calculated on the highest five consecutive
years, for persons with 30 or more years of service. Employees with less than 30
years of service will have their retirement benefits proportionally reduced.
The following table sets forth the Employees' Pension Plan and Trust benefits at
various years of service and salary levels.
PENSION TABLE
Years of Service (1)
SALARY 10 15 20 25 30
------ ------ ------ ------ ------ ------
120,000 20,000 30,000 40,000 50,000 60,000
100,000 16,666 25,000 33,333 41,666 50,000
75,000 12,500 18,750 25,000 31,250 37,500
50,000 8,333 12,500 16,666 20,833 25,000
- ---------------------
(1) Assumes a Lifetime Only Benefit (benefits cease upon employees death).
Under the Employees' Pension Plan and Trust, Mr. Mewbourne would have a lifetime
benefit of $5,200 per month based on his current base salary of $124,800 and
assuming he works until age 65 at which time he would have 36 years of
employment.
Mewbourne Holdings, Inc. maintains an incentive compensation plan for
key personnel, which is funded by overriding royalty interests burdening
prospects developed by the drilling program manager. Payments to employees are
discretionary and are made net of expenses. Gross payments from the plan to
employees were approximately $559,000 for the fiscal year ended June 30, 1999.
The interests in the oil and gas leases to be acquired by the drilling program
will not be burdened by plan royalties and the partnerships will not bear any
costs or expenses attributable to the plan.
Non-Cash Compensation of Executive Officer. Mr. Mewbourne, as the sole
executive officer of the managing partner and the drilling program manager, was
provided club memberships for use in performing his assigned duties and from
time to time used such memberships for personal purposes. To the extent any club
membership was used for non-reimbursed, non-job related purposes, a
proportionate part of the cost of providing such use would have constituted
remuneration to the user. The managing partner and the drilling program manager
are unable without unreasonable effort to determine the extent of such
non-reimbursed, non-job related use, but believes that during the year ended
December 31, 1999 the amounts of such benefits received by such officer did not
exceed 10% of such officer's cash compensation for the year.
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CERTAIN TRANSACTIONS
Participation in Drilling Program Activities. Mr. Mewbourne and/or his
affiliates, other than affiliated programs, have historically invested directly
in the exploration and development activities of Mewbourne Oil Company during
the past 34 years. In addition, he and/or his affiliates, other than affiliated
programs, have been an investor in the joint ventures and drilling agreements
through which, other investors participated in various Mewbourne Oil Company
managed programs. Mr. Mewbourne's and his affiliates, other than affiliated
programs, annual participation varied considerably both in level of investment
and form, but in general approximated 25% to 50% of the annual expenditures.
Mr. Mewbourne intends to invest directly and/or indirectly alongside
each partnership in the activities of each drilling program, however, we cannot
assure that the amount of Mr. Mewbourne's participation will be in accordance
with his historical custom. The amount of such investment will be subject to
many variables, including the availability of working interests in the oil and
gas leases, the amount of capital available to each partnership from
subscriptions, the timing of the drilling activities, and other such matters.
CONFLICTS OF INTEREST
o The managing partner currently manages and in the future will sponsor
and manage other partnerships similar to the partnerships in which
interests are being offered.
o The managing partner will decide which prospects each partnership will
acquire.
o The drilling program manager will act as the operator for program
wells, under the operating agreement, the terms of which have not been
negotiated by non-affiliated persons.
o The managing partner and its affiliates will contribute oil and gas
leases and sell other property to the drilling program and related
partnerships.
o The managing partner is a general partner of numerous other
partnerships and owes duties of good faith and fair dealing to such
other partnerships.
o The managing partner and its affiliates engage in significant drilling,
operating, and producing activities for other partnerships.
o Affiliates of the managing partner are eligible to purchase interests,
and subject to limitations, interests purchased by an affiliate will
have voting rights under the partnership agreement.
FIDUCIARY RESPONSIBILITY OF THE MANAGING PARTNER
The contemplated activities of each partnership will involve decisions
by the managing partner, on behalf of each partnership, and the drilling program
manager, on behalf of the related drilling program, and transactions between the
partnership, the related drilling program, the managing partner, or affiliates
thereof. Because of the common control of each partnership, each drilling
program, the managing partner, the drilling program manager, and other
affiliates thereof, any such decisions or transactions will lack the benefits of
arm's-length bargaining and will necessarily involve conflicts of interest. The
managing partner is accountable to each partnership as a fiduciary and is
required to act in good faith in the best interests of each partnership at all
times. The managing partner will attempt, in good faith, to resolve all
conflicts of interest in a fair and equitable manner with respect to all persons
affected by those conflicts of interest. Nevertheless, the actions of the
managing partner may not be the most advantageous to a partnership and could
fall short of the full exercise of such fiduciary duty. No provision has been
made for an independent review of conflicts of interest.
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The partnerships are organized under Delaware law, and under Delaware
law the general partner of a partnership owes a fiduciary duty to the
partnership and to its partners. Under Delaware law, the managing partner will
owe the general and limited partners a duty of good faith, fairness, and
loyalty. In this regard, the managing partner is required to supervise and
direct the activities of each partnership prudently and with that degree of
care, including acting on an informed basis, which an ordinarily prudent person
in a like position would use under similar circumstances. Moreover, the managing
partner must act at all times in the best interests of each partnership and the
general and limited partners. Since the law in this area is rapidly developing
and changing, investors who have questions concerning the responsibilities of
the managing partner should consult their own counsel.
Limitations on the Fiduciary Obligations of the Managing Partner and
the Managing Partner's Responsibility to Determine the Application of the
Limitations. The partnership agreement contains provisions which modify what
would otherwise be the applicable Delaware law relating to the fiduciary
standards of the managing partner to the general and limited partners. The
fiduciary standards in the partnership agreement could be less advantageous to
the general and limited partners and more advantageous to the managing partner
than the corresponding fiduciary standards otherwise applicable under Delaware
law, specifically:
o a partnership may indemnify and hold harmless the managing
partner and its affiliates,
o the managing partner is required to devote only so much of its
time as is necessary to manage the affairs of the partnership,
o the managing partner and its affiliates may conduct business
with a partnership in a capacity other than as a sponsor,
o the managing partner and any of its affiliates may pursue
business opportunities that are consistent with a
partnership's investment objectives for their own account, and
o the managing partner may manage multiple programs
simultaneously.
As summarized above the partnership agreement contains provisions which
are intended to limit the liability of the managing partner or any affiliate of
the managing partner for any act or omission within the scope of authority
conferred upon them under the partnership agreement or drilling program
agreement if the managing partner has determined in good faith, as of the time
of the conduct or omission, that such conduct or omission was in the best
interest of a partnership and that it did not constitute negligence or
misconduct. The managing partner would be subject to a conflict of interest in
making any such determination. The limitation upon the fiduciary standards in
the partnership agreement could be less advantageous to the general and limited
partners and more advantageous to the managing partner than the corresponding
fiduciary standards otherwise applicable under Delaware law. The purchase of
interests may be deemed as consent to the fiduciary standards set forth in the
partnership agreement. As a result of these provisions in the partnership
agreement, the general and limited partners may find it more difficult to hold
the managing partner responsible for acting in the best interests of a
partnership and its general and limited partners than if the fiduciary standards
of the otherwise applicable Delaware law governed the situation.
The partnership agreement and drilling program agreement provide for
indemnification of the managing partner, the drilling program manager and
affiliates of the drilling program manager and their respective officers and
directors against claims arising from conduct or omission on behalf of a
partnership or a drilling program. Such indemnification will be available if the
managing partner determines in good faith, as of the time of the conduct or
omission, that the conduct or omission was in the best interest of the related
partnership and that it did not constitute negligence or misconduct. The
managing partner would be subject to a conflict of interest in making any such
determination as to whether the managing partner or its affiliates should be
indemnified, and the general and limited partners must rely upon the integrity
of the managing partner in making such determination.
Where the question has arisen, courts have held that an investor
partner may institute a legal action called a class action on behalf of himself
and all other similarly situated investor partners to recover damages for a
breach by a general partner of his fiduciary duty. An investor partner may also
institute a legal action called a derivative suit on behalf of the partnership
to recover damages from third parties. In addition, investor partners may have
the right, subject to procedural and jurisdictional requirements, to bring
partnership class actions in federal courts to enforce their rights under the
federal securities laws. Further, investor partners who have suffered losses in
connection with the purchase or sale of their interests in a partnership may be
able to recover such losses from a general partner where
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the losses result from a violation by the general partner of the antifraud
provisions of the federal securities laws. The burden of proving such a breach,
and all or a portion of the expense of such lawsuit, would have to be borne by
the investor partner bringing such action. In the event of a lawsuit for a
breach of its fiduciary duty to a partnership and/or the general and limited
partners, the managing partner, depending upon the particular circumstances
involved, might be able to avail itself under Delaware law of various defenses
to the lawsuit.
In the performance of its duties as operator under an operating
agreement, the program manager is required to act in accordance with a prudent
operator standard. In general, under the prudent operator standard, a person is
required to act in the same manner as an ordinary prudent operator would act
under the same or similar circumstances. The prudent operator standard is
significantly less restrictive than the fiduciary duty imposed upon the managing
partner. Conduct under the prudent operator standard may not necessarily be the
most advantageous to a partnership and under such standard it would be more
difficult to hold the program manager responsible for acts or omissions in its
capacity as operator than if the fiduciary duty standard were otherwise
applicable.
FARMOUTS
Any farmout or similar agreement pertaining to a partnership's oil and
gas leases must comply with the rules, restrictions, and guidelines described in
this prospectus and the limitations set forth in the partnership agreement, and
will be subject to the following conditions:
o the managing partner must determine that the farmout or
similar agreement is in the best interests of the partnership,
o the terms of the farmout or similar agreement must be
consistent with, and in any case no less favorable to the
partnership than, those utilized in the same geographic area
for similar arrangements, and
o if the assignee under the farmout is the managing partner or
its affiliate then, the farmout is subject to the same
restrictions as applicable to a purchase of undeveloped
property from the partnership. See "Proposed Activities --
Transactions with Affiliates -- Purchase of Leases from the
Partnership."
The decision of the managing partner with respect to making a farmout
and the terms of a farmout to an affiliate may involve conflicts of interest, as
the managing partner or the affiliate may benefit from cost savings and
reduction of risk, and in the event of a farmout to an affiliate, the managing
partner will represent both the partnership and the affiliate.
None of a partnership's oil and gas leases will be farmed out unless
the managing partner, determines that:
o the partnership lacks sufficient funds to drill on the oil and
gas lease and cannot obtain suitable alternative financing for
such drilling,
o the value of the oil and gas lease has been reduced by events
occurring or information disclosed to such managing partner
after assignment of the oil and gas lease to the partnership
so that drilling would no longer be desirable for the
partnership,
o drilling on the oil and gas lease would result in an excessive
concentration of the partnership's funds creating, in the
managing partner's opinion, undue risk to the partnership, or
o the best interests of the partnership would be served by the
farmout.
A partnership will acquire only those oil and gas leases that are
reasonably required for the stated purpose of the partnership, and no oil and
gas leases will be acquired for the purpose of subsequent sale or farmout,
unless the acquisition of the oil and gas leases by that partnership is made
after a well has been drilled to a depth sufficient to
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indicate that the acquisition is believed to be in the best interest of the
partnership. The managing partner is not permitted to farmout a property for the
primary purpose of avoiding payment of the costs relating to drilling on the
property that would otherwise be allocable to the managing partner. See
"Proposed Activities -- Farmouts," and "Conflicts of Interest -- Sale of Leases
to a Partnership" and "Purchase of Leases from a Partnership."
PURCHASE OF LEASES FROM A PARTNERSHIP
Neither the managing partner nor its affiliate, including an affiliated
program, may purchase or acquire any oil and gas lease from a partnership,
directly or indirectly, except in transactions that are fair and reasonable to
the partnership and then subject to the following conditions:
o a sale, transfer or conveyance, including a farmout, of an oil
and gas lease not having any proved developed reserves
attributable to it from a partnership to the managing partner,
or its affiliate, other than an affiliated program, must be
made at the higher of the lease acquisition costs or fair
market value,
o a sale, transfer or conveyance of an oil and gas lease (having
proved developed reserves attributable to it from the
partnership to the managing partner or its affiliate, other
than an affiliated program in which the interest of the
managing partner or its affiliate is substantially similar to
or less than its interest in the partnership, is not permitted
except in connection with the liquidation of the partnership
and then only at fair market value,
o except in connection with farmouts or joint ventures made in
compliance with the partnership agreement. which is summarized
in the final paragraph of the subsection entitled "Sale of
Lease to the partnership" below, a transfer of an undeveloped
oil and gas lease from the partnership to an affiliated
program must be made at fair market value if the oil and gas
lease has been held for more than two years; otherwise, if the
managing partner deems it to be in the best interest of the
partnership, the transfer may be made at the lease acquisition
costs, and
o except in connection with farmouts made in compliance with the
restrictions described in the partnership agreement, a
transfer of any oil and gas lease from the partnership to an
affiliated program, whose investment obligation is to directly
acquire, hold, operate and/or dispose of producing oil and gas
properties, must be made at fair market value if the oil and
gas lease has been held for more than six months or there have
been significant expenditures made in connection with the oil
and gas lease; otherwise, if the managing partner deems it to
be in the best interest of the partnership, the transfer may
be made at the lease acquisition costs as adjusted for
intervening operations.
A determination of fair market value must be supported by an appraisal from an
independent expert. Such opinion and any associated supporting information must
be maintained in a drilling program's records for at least six years.
SALE OF LEASES TO A PARTNERSHIP
The managing partner has discretion in selecting the oil and gas leases
to be contributed to a partnership by the managing partner and the location and
type of operations that a partnership will conduct on the contributed oil and
gas leases. A portion of such oil and gas leases may be part of the managing
partner's existing inventory. In determining which oil and gas leases should be
contributed to a partnership, if the managing partner or its affiliates has oil
and gas leases in its own inventory at the time, the managing partner would be
subject to a conflict of interest in selecting properties for the partnership
out of its or an affiliate's inventory or from third party sellers.
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ADJACENT ACREAGE
A drilling program may not drill any well for the purpose of proving or
disproving the existence of oil or gas on any adjacent acreage held by the
managing partner or an affiliate of the managing partner. Nevertheless, such
drilling activities may incidentally develop information valuable to the
managing partner or affiliates of the managing partner in evaluating their
nearby acreage at no cost to them. Mewbourne Oil Company or its affiliates also
may retain an ownership interest in an oil and gas lease contributed by the
managing partner to a drilling program and the use of drilling program funds to
drill a well on such oil and gas lease will reduce the cost and risk to the
managing partner or its affiliates of drilling on such oil and gas lease.
Accordingly, a conflict of interest will exist between the interest of the
partnership and the interest of the managing partner in selecting the location
and type of operations which the related drilling program will conduct on
drilling program leases where the managing partner or affiliates of the managing
partner own oil and gas leases in the vicinity of the drilling program leases or
retain an ownership interest in the drilling program leases. In addition, the
liability of the managing partner and its affiliates to the partnerships is
limited as set forth under "-- Fiduciary Responsibility of the Managing Partner"
and such limitations significantly increase the potential conflicts that may
arise with regard to the acquisition and operation of adjacent acreage.
OTHER ACTIVITIES
As summarized in "Risk Factors -- Particular Risks Relating to the
Interests -- Limitations on the Fiduciary Obligations of the Managing Partner
and the Managing Partner's Responsibility to Determine the Application of the
Limitations," the partnership agreement modifies the fiduciary duties owed by
the managing partner or its affiliates to a partnership and the general and
limited partners by specifically modifying the duties otherwise owed under
Delaware law. The partnership agreement specifically permits the managing
partner and its affiliates to engage in and possess interests in other business
ventures of any and every type and description, independently or with others,
including without limitation the acquisition, ownership, exploration,
development, operation, and management of oil and gas properties for themselves
and other persons, and the organization and management of other partnerships and
joint ventures similar to the partnerships; provided, however, except as
otherwise set forth in the partnership agreement and as described in "Proposed
Activities -- Transactions with Affiliates," the managing partner and its
affiliates may pursue business opportunities that are consistent with the
partnerships' investment objectives for their own account only after they have
determined that such opportunity either cannot be pursued by a partnership
because of insufficient funds or because it is not appropriate for a partnership
under the existing circumstances. The managing partner and its affiliates
currently act as the managing general partner of several other oil and gas
drilling partnerships. See "Prior Activities." The business of these
partnerships may be considered competitive with the business of the partnerships
in areas such as markets for production, use of equipment, and access to the
time and financial resources of management, as well as in other areas. In
addition, the managing partner or its affiliates may sponsor additional drilling
partnerships and other oil and gas partnerships in the future. Therefore, the
managing partner will be acting on behalf of each partnership as managing
partner, on behalf of existing partnerships, and on behalf of other partnerships
and joint ventures which the managing partner or its affiliates may sponsor in
the future. As a result of these activities of the managing partner and its
affiliates, circumstances may arise where the interest of the managing partner
or of its affiliates in such independent ventures will conflict with those of
the general and limited partners with respect to the acquisition of prospects,
the utilization of available drilling services and similar matters. A conflict
of interest may arise, for example, when a partnership, the managing partner and
other prior or future oil and gas partnerships in which the managing partner or
its affiliate has an interest will have an opportunity to acquire the same oil
and gas leases. In these situations, it may be expedient for the managing
partner to favor one partnership or venture over another. It is possible that
the managing partner or its affiliates will be in the process of acquiring oil
and gas leases for inclusion in other drilling partnerships at the same time
that they are acquiring oil and gas leases for inclusion in a drilling program.
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CONTRACTS WITH MEWBOURNE AND AFFILIATES
The managing partner and its affiliates do not own any drilling rigs or
service companies, and except for the providing of gas compressors from an
affiliate of the managing partner and for the operating agreement, the managing
partner currently does not anticipate that it will enter into contracts and
agreements with either partnership for the rendering of services or the sale and
lease of supplies and equipment. However, the partnership agreement specifically
permits a partnership and the managing partner to enter into agreements for such
purposes and for the lending of money to a partnership. Neither the managing
partner nor any affiliate of the managing partner will enter into any agreement
with a partnership to provide services, supplies and equipment unless:
(a) the managing partner or such affiliate is engaged
independently of the partnership as an ordinary and ongoing
business in the business of rendering such services or selling
or leasing such equipment and supplies to a substantial extent
to other persons in the oil and gas industry in addition to
partnerships or drilling programs in which the managing
partner or such affiliate has an interest,
(b) the compensation, price, or rental is competitive, determined
as of the time that the contract is entered into, with the
compensation, price, or rental of other persons in the area
engaged in the business of rendering comparable services or
selling or leasing comparable equipment and supplies which
could reasonably be made available to the partnership, and
(c) if the managing partner or such affiliate is not engaged in a
business within the meaning of clause (a) above, then such
compensation, price, or rental is the lesser of the cost of
such services, equipment, or supplies to the managing partner
or such affiliate or the competitive rate which could be
obtained in the area. Any loan of money to a partnership by
the managing partner or its affiliate may not bear interest in
excess of the lesser of the rate the managing partner or such
affiliate is required to pay on similar borrowings or the
highest lawful rate, or in any event at a rate in excess of
the amount which would be charged to the partnership by
independent third parties for the same purpose. See
"Additional Financing."
All contracts between a partnership and the managing partner or its
affiliate may be terminated upon the vote or written consent of more than 50% of
the interest of the general and limited partners without penalty on 60 days'
advance written notice. Notwithstanding any provision to the contrary, the
managing partner and its affiliates may not profit by drilling in contravention
of their fiduciary obligations to the general and limited partners. In addition,
no rebates may be received by the managing partner or any affiliate nor may the
managing partner or any affiliate participate in any reciprocal business
arrangements.
MEWBOURNE OIL COMPANY AS OPERATOR
Under the terms of each drilling program agreement, the drilling
program manager has agreed to serve as operator of program wells. Each drilling
program agreement specifically provides that any operating agreement pertaining
to the drilling program manager's acting as an operator of program wells will be
subject to the limitations set forth in the related partnership agreement with
respect to contracts for the rendering of services and the sale and lease of
supplies and equipment, which limitations are described in the preceding
paragraph. In the event that non-affiliated parties do not participate, or have
a small interest, in a drilling program's prospects there will be no independent
oversight with respect to the competitiveness of the operating agreements
entered into with the drilling program manager. See "Proposed Activities --
Operations" and "Compensation and Reimbursement -- Compensation as Operator."
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OWNERSHIP OF INTERESTS BY THE MANAGING PARTNER OR ANY AFFILIATES
The managing partner and its affiliates are eligible to subscribe for
interests, provided that any interests so purchased must be purchased for
investment purposes only and not for the purpose of resale or any further public
distribution. It is the managing partner's current intention that the managing
partner and/or an affiliate of the managing partner will subscribe for such
number of interests as may be necessary for each partnership in which interests
are being offered to receive the minimum subscription amount of 1,000 interests
($1,000,000). The number of interests in a partnership that may be purchased by
the managing partner and/or its affiliates is not subject to any specific
maximum limitations but instead depends upon the number of subscriptions for
interests received and accepted from non-affiliates. However, although there are
no limitations upon the number of interests that may be purchased by an
affiliate, the managing partner does not intend to purchase any interests in a
partnership if the partnership has already received the minimum subscription
amount and the managing partner does not intend to purchase any more interests
in a partnership than necessary to ensure that such partnership receives the
minimum subscription amount. Any interests purchased by the managing partner or
its affiliates will have voting rights under the partnership agreement, provided
that during the time period that Mewbourne Development Corporation or its
affiliate is serving as the managing partner of a partnership any interests
owned by the managing partner or its affiliates which in the aggregate represent
more than 20% of the total interests held by investor general and limited
partners in that partnership shall not have any voting rights under the
partnership agreement and shall not be counted for voting purposes. In addition,
during the time period that Mewbourne Development Corporation or its affiliate
is serving as the managing partner of a partnership, none of the interests owned
by the managing partner or its affiliates shall be counted for voting purposes
or for purposes of determining a quorum or have any voting rights under the
partnership agreement concerning the removal of the managing partner or any
transaction between that partnership and the managing partner or its affiliates.
Notwithstanding the voting limitation imposed upon interests owned by the
managing partner or its affiliates, to the extent that interests in a
partnership are acquired by the managing partner or its affiliates, such
ownership interests has the effect of diluting the voting power of the other
general and limited partners in that partnership. The exercise of the voting
rights of any interests owned by the managing partner or its affiliates could
give rise to a conflict of interest between the managing partner and the
investor general and limited partners.
PRIOR ACTIVITIES
PRIOR PARTNERSHIPS
The managing partner has historically originated and managed drilling
and development activities through which a limited number of qualified
participants, including other oil and gas companies, acquired individual working
interests in leases by means of joint ventures and drilling agreements. The
structure of such transactions, including the manner in which costs and revenues
are shared varied considerably and in each case are substantially different from
those of an investor partner investing in a partnership.
During the period 1977-1980, affiliates of the general partner
sponsored a series of five private limited partnerships. The general partner has
also sponsored eleven public partnerships, Mewbourne Development Partners 93-A,
L.P., Mewbourne Development Partners 93-B, L.P., Mewbourne Development Partners
94-A, L.P., Mewbourne Development Partners 94-B, L.P., Mewbourne Development
partners 94-C, L.P., Mewbourne Energy Partners 95-A, L.P., Mewbourne Energy
Partners 95-B, L.P., Mewbourne Energy Partners 96-A, L.P., Mewbourne Energy
Partners 97-A, L.P., Mewbourne Energy Partners 98-A, L.P., Mewbourne Energy
Partners 99-A, L.P. and two private partnerships, Mewbourne Development Partners
1992 GP and Mewbourne Energy Partners 1994 Private L.P. Except for the above
described partnerships, neither the general partner nor any of its affiliates
have sponsored any private or public partnerships within the past ten years. The
financial disclosure provided below is presented on a tax basis of accounting.
FOR PURPOSES OF MAKING AN INVESTMENT DECISION, THE STRUCTURE AND
ACTIVITIES OF THE FIVE PRIVATE LIMITED PARTNERSHIPS SPONSORED DURING THE YEARS
1977 THROUGH 1980 ARE NOT COMPARABLE TO THE PARTNERSHIPS. IN PARTICULAR, THE
FIVE PRIVATE LIMITED PARTNERSHIPS WERE STRUCTURED TO INCLUDE ONE OR MORE OF THE
FOLLOWING ATTRIBUTES:
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66
o ADDITIONAL ASSESSMENTS WERE REQUIRED FROM THE INVESTORS AS
CONTRASTED TO THE CURRENT OFFERING WHICH DOES NOT ALLOW FOR
ANY ADDITIONAL ASSESSMENTS,
o SIGNIFICANT INDEBTEDNESS WAS INCURRED AS CONTRASTED TO THE
CURRENT OFFERING WHICH CONTEMPLATES ONLY LIMITED BORROWINGS
AND IN LIMITED CIRCUMSTANCES,
o EXCESS INCOME WAS REINVESTED IN ADDITIONAL DRILLING ACTIVITIES
AS CONTRASTED TO THE PROPOSED OFFERING WHICH DOES NOT
CONTEMPLATE SIGNIFICANT REINVESTMENT OF EXCESS INCOME,
o ACTIVITIES WERE ENGAGED IN THAT ARE NOT COMPARABLE TO THE
ACTIVITIES PROPOSED TO BE ENGAGED IN BY THE CURRENT OFFERING,
INCLUDING DRILLING EXPLORATORY WELLS, AS CONTRASTED TO THE
CURRENT OFFERING WHICH CONTEMPLATES THE DRILLING OF PRIMARILY
DEVELOPMENT WELLS, AND/OR
o THE SHARING OF PARTNERSHIP'S REVENUES AND COSTS BETWEEN THE
MANAGING PARTNER AND THE INVESTORS WAS MADE IN A SIGNIFICANTLY
DIFFERENT METHOD AS CONTRASTED TO THE CURRENT OFFERING.
DUE TO THESE SIGNIFICANT DIFFERENCES, THE DISCLOSURE REGARDING THE PRIOR
ACTIVITIES OF THE FIVE PRIVATE LIMITED PARTNERSHIPS MAY NOT BE RELEVANT TO A
PROSPECTIVE SUBSCRIBER MAKING AN INVESTMENT DECISION WITH RESPECT TO A
PARTNERSHIP AND ARE NOT INDICATIVE OF THE RESULTS THAT MAY BE ACHIEVED BY EITHER
PARTNERSHIP.
The following table is to indicate the total amount of administrative
costs incurred, as of December 31, 1999, by partnerships sponsored by the
managing partner or its affiliates, and the percentage of subscriptions raised
in each partnership as compared to other costs incurred by each partnership.
Other Costs(1) Administrative Costs
----------------------------- ------------------------------
Percentage of Percentage of
Partnership(3) Amount Subscriptions Amount Subscriptions
- -------------------------------------------------------- ------------ --------------- ------------- ---------------
Mewbourne Oil, Ltd. 1977 (4) ......................... $3,386,123 100.75% $ 783,973 23.33%
Mewbourne Oil, Ltd. 1978 ............................. 12,178,316 275.15% 2,457,127 55.52%
Mewbourne Oil, Ltd. 1978B (5) ........................ 7,901,956 196.02% 1,322,538 32.81%
Mewbourne Oil, Ltd. 1979 (4).......................... 7,005,778 162.89% 1,267,283 29.46%
Mewbourne Oil, Ltd. 1980 (4).......................... 2,783,153 135.73% 398,584 19.44%
Mewbourne Development Partners 92 GP.................. 1,189,057 101.58% 39,651 3.39%
Mewbourne Development Partners 93-A LP................ 1,341,851 96.21% 35,782 2.57%
Mewbourne Development Partners 93-B LP................ 1,351,817 103.11% 42,367 3.23%
Mewbourne Development Partners 94-A LP................ 1,268,156 105.24% 40,045 3.32%
Mewbourne Development Partners 94-B LP................ 1,093,572 107.28% 49,355 4.84%
Mewbourne Development Partners 94-C LP................ 1,097,775 105.60% 49,598 4.77%
Mewbourne Energy Partners 1994 Private LP............. 1,555,074 104.73% 991 .07%
Mewbourne Energy Partners 95-A, L.P................... 1,656,862 101.32% 85,758 5.24%
Mewbourne Energy Partners 95-B, L.P................... 2,037,059 100.28% 28,203 1.39%
Mewbourne Energy Partners 96-A, L.P................... 4,001,784 102.32% 84,195 2.15%
Mewbourne Energy Partners 97-A, L.P................... 3,576,736 112.73% 83,001 2.62%
Mewbourne Energy Partners 98-A, L.P................... 3,527,883 94.45% 21,568 .58%
Mewbourne Energy Partners 99-A, L.P................... 3,687,193 64.38% 0 .00%(2)
60
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- -----------------------
(1) Includes lease acquisition costs, and all direct costs.
(2) Represents less than .01%.
(3) Unless otherwise noted, all partnerships are currently operating.
(4) This partnership was terminated November 30, 1994.
(5) This partnership was terminated September 1, 1996.
PAST COMPENSATION
In connection with a series of five private limited partnerships
sponsored by an affiliate of the managing partner during 1977-1980 and two
private limited partnerships and a series of eleven public limited partnerships
sponsored by the managing partner since December 1992, such partnerships have
made the following payments to the managing partner and its affiliates.
PAYMENTS MADE TO THE MANAGING PARTNER AND AFFILIATES
December 31, 1999
Nonrecurring
Management
and Administrative
Organization Lease Operating Cost
Partnership Fee Acquisition (1) Equipment Fees Reimbursement
==================================================== =============== ============== ============ ============= ===============
Mewbourne Oil, Ltd. 1977(2)......................... $35,000 $300,689 $ 795,925 $1,226,840 $ 753,129
Mewbourne Oil, Ltd. 1978A(4)........................ 54,450 639,122 2,242,378 4,251,920 2,017,279
Mewbourne Oil, Ltd. 1978B(3)........................ 47,216 332,025 1,584,709 2,608,629 1,250,786
Mewbourne Oil, Ltd. 1979(2)......................... 52,230 490,024 1,357,496 2,169,170 1,194,485
Mewbourne Oil, Ltd. 1980(2)......................... 26,628 301,720 472,053 307,664 491,564
Mewbourne Development Partners 92 GP(4)............. 63,162 267,012 206,087 148,894 39,651
Mewbourne Development Partners 93-A, L.P.(4)........ 61,568 107,736 284,788 291,267 35,782
Mewbourne Development Partners 93-B, L.P.(4)........ 57,870 170,348 269,789 234,211 42,367
Mewbourne Development Partners 94-A, L.P.(4)........ 53,193 226,601 220,389 159,342 40,045
Mewbourne Development Partners 94-B, L.P.(4)........ 44,996 86,100 210,303 169,688 49,355
Mewbourne Development Partners 94-C, L.P.(4)........ 45,887 95,606 207,651 166,934 49,598
Mewbourne Energy Partners 1994 Private L.P.(4)...... 0 225,612 187,265 176,869 991
Mewbourne Energy Partners 95-A, L.P.(4)............. 91,763 375,864 288,861 214,384 85,758
Mewbourne Energy Partners 95-B, L.P.(4)............. 19,909 519,456 222,045 186,804 28,203
Mewbourne Energy Partners 96-A, L.P.(4)............. 164,872 946,832 726,810 415,967 84,195
Mewbourne Energy Partners 97-A, L.P. (4)............ 99,521 758,185 602,842 282,963 83,001
Mewbourne Energy Partners 98-A, L.P.(4)............. 76,882 848,953 548,447 238,572 21,568
Mewbourne Energy Partners 99-A, L.P.(4)............. 0 0 326,237 69,886 0
- --------------------
(1) Interests in oil and gas properties were acquired at cost from
Mewbourne Oil Company.
(2) This partnership was terminated on November 30, 1994.
(3) This partnership was terminated on September 1, 1996.
(4) This partnership is currently operating.
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68
The following table is presented to indicate certain sale distribution
characteristics concerning partnerships sponsored by the managing partner or its
affiliates.
PRIOR PERFORMANCE IS NOT INDICATIVE OF FUTURE RESULTS
EXPERIENCE IN RAISING FUNDS
Date of First
Revenue Number of Maximum
Partnership Funding Date Distribution Units Sold Price Per Unit Offering Size
================================================ ============= ============= ============== ============= =============
Mewbourne Oil, Ltd. 1977(1)..................... 8/25/77 6/27/78(2)(3) 193.0 $10,000 $3,000,000
Mewbourne Oil, Ltd. 1978A(8).................... 5/4/78 2/24/84(2)(3) 288.0 10,000 4,000,000
Mewbourne Oil, Ltd. 1978B (7)................... 12/6/78 12/31/80(2)(3) 286.5 10,000 4,000,000
Mewbourne Oil, Ltd. 1979(1)..................... 7/10/79 12/8/80(2)(3) 312.5 10,000 4,000,000
Mewbourne Oil, Ltd. 1980(5)(1).................. 5/22/80 -- (2)(3) 147.0 10,000 4,000,000
Mewbourne Development Partners 92 GP(8)......... 12/31/92 5/18/93(3) 116.0 10,000 5,000,000
Mewbourne Development Partners 93-A, L.P.(8).... 10/11/93 2/21/94 1,382 1,000(6) 10,000,000
Mewbourne Development Partners 93-B, L.P.(8).... 12/31/93 4/25/94 1,299 1,000(6) 10,000,000
Mewbourne Development Partners 94-A, L.P.(8).... 6/30/94 10/24/94 1,194 1,000(6) 10,000,000
Mewbourne Development Partners 94-B, L.P.(8).... 11/4/94 3/21/95 1,100 1,000(6) 10,000,000
Mewbourne Development Partners 94-C, L.P.(8).... 12/30/94 4/28/95 1,030 1,000(6) 10,000,000
Mewbourne Energy Partners 1994 Private L.P.(8).. 12/30/94 4/28/95 73.5 20,000 10,000,000
Mewbourne Energy Partners 95-A, L.P.(8)......... 10/11/95 2/19/96 1,619 1,000(6) 10,000,000
Mewbourne Energy Partners 95-B, L.P.(8)......... 12/29/95 5/20/96 2,011 1,000(6) 10,000,000
Mewbourne Energy Partners 96-A, L.P.(8)......... 11/7/96 3/20/97 3,872 1,000(6) 10,000,000
Mewbourne Energy Partners 97-A, L.P.(8)......... 11/9/97 3/20/98 3,141 1,000(6) 10,000,000
Mewbourne Energy Partners 98-A, L.P.(8)......... 11/20/98 3/25/99 3,698 1,000(6) 10,000,000
Mewbourne Energy Partners 99-A, L.P.(8)......... 11/22/99 N/A 5,727 1,000(6) 10,000,000
Contributions
From
Partnership Investors(4)
================================================ ==============
Mewbourne Oil, Ltd. 1977(1)..................... $2,891,000
Mewbourne Oil, Ltd. 1978A(8).................... 3,456,000
Mewbourne Oil, Ltd. 1978B (7)................... 3,581,250
Mewbourne Oil, Ltd. 1979(1)..................... 3,906,250
Mewbourne Oil, Ltd. 1980(5)(1).................. 1,837,500
Mewbourne Development Partners 92 GP(8)......... 1,160,000
Mewbourne Development Partners 93-A, L.P.(8).... 1,382,000
Mewbourne Development Partners 93-B, L.P.(8).... 1,299,000
Mewbourne Development Partners 94-A, L.P.(8).... 1,194,000
Mewbourne Development Partners 94-B, L.P.(8).... 1,010,000
Mewbourne Development Partners 94-C, L.P.(8).... 1,030,000
Mewbourne Energy Partners 1994 Private L.P.(8).. 1,470,000
Mewbourne Energy Partners 95-A, L.P.(8)......... 1,619,000
Mewbourne Energy Partners 95-B, L.P.(8)......... 2,011,000
Mewbourne Energy Partners 96-A, L.P.(8)......... 3,872,000
Mewbourne Energy Partners 97-A, L.P.(8)......... 3,141,000
Mewbourne Energy Partners 98-A, L.P.(8)......... 3,698,000
Mewbourne Energy Partners 99-A, L.P.(8)......... 5,727,000
- ----------------------
(1) This partnership was terminated on November 30, 1994.
(2) Cash Distributions reflect the policy to retain initial revenues to
reinvest in additional wells. Retention of revenues delayed the
commencement of distributions to the participants.
(3) The 1977 partnership retained $553,549 of distributable operating cash
flow to reinvest in additional drilling. The 1978A, 1978B, 1979 and
1980 partnerships retained $1,836,329, $3,580,177, $2,326,134 and
$223,343 of distributable operating cash flow to reinvest in additional
drilling, respectively, and $5,391,821, $30,072, $125,133 and $732,939
of distributable operating cash flow was used to repay borrowings of
the partnership, respectively. The 92 GP, 93-A, 93-B, 94-A, 94-B, 94-C
MEP 94-Private and 97-A partnerships retained $64,165, $24,614,
$76,838, $82,864, $124,975, $111,208, $25,852, and $303,818
respectively of distributable operating cash flow to complete drilling
operations.
(4) Includes initial subscriptions plus additional assessments, if any,
under the provisions of each offering. Also includes contributions by
the managing partner and its affiliates in each of public programs
previously sponsored by the managing partner. Such contributions were
in the amounts of $480,000, $400,000, $366,000, $437,500 and $660,000
in each of Mewbourne Development partners 93-A, L.P., Mewbourne
Development partners 93-B, L.P., Mewbourne Development partners 94-A,
L.P., Mewbourne Development partners 94-B, L.P., Mewbourne Development
partners 94-C, L.P., respectively.
(5) The activities of this partnership consisted solely of exploratory
drilling.
(6) Each partnership required a minimum investment of five units or $5,000.
(7) This partnership was terminated September 1, 1996.
(8) This partnership is currently operating.
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PREVIOUS DRILLING ACTIVITIES
The following table reflects the previous drilling activity of
partnerships sponsored by the managing partner or its affiliates.
PRIOR PERFORMANCE IS NOT INDICATIVE OF FUTURE RESULTS
DRILLING RESULTS
Inception Through December 31, 1999
Gross(1) Net(2)
-------------------------------------------------------------------
Percent
Partnership Completed Dry Completed Dry Completed
=================================================== ============= ============= ============= =========== =============
Mewbourne Oil Ltd., 1977-A(3) ....................... 15 4 8.00 2.33 77%
Mewbourne Oil Ltd., 1978A(7) ........................ 35 11 20.68 6.58 76%
Mewbourne Oil Ltd., 1978B (6) ....................... 31 8 15.66 4.10 79%
Mewbourne Oil Ltd., 1979(3) ......................... 27 12 13.60 5.62 71%
Mewbourne Oil Ltd., 1980(3)(4) ...................... 34 11 3.31 0.96 78%
----- ----- ----- ----- -----
Total ......................................... 142 46 61.25 19.59 76%
----- ----- ----- ----- -----
Mewbourne Development Partners 92 GP(7) ............. 6 4 0.73 0.56 56%
Mewbourne Development Partners 93-A, L.P.(7) ........ 9 0 2.57 0 100%
Mewbourne Development Partners 93-B, L.P.(7) ........ 14 0 2.09 0 100%
Mewbourne Development Partners 94-A, L.P.(7) ........ 8 1 1.19 0.14 89%
Mewbourne Development Partners 94-B, L.P.(7) ........ 5 0 1.28 0 100%
Mewbourne Development Partners 94-C, L.P.(7) ........ 4 0 1.30 0 100%
Mewbourne Energy Partners 1994 Private L.P.(7) ...... 5 1 3.03 0.33 90%
Mewbourne Energy Partners 95-A, L.P.(7) ............. 7 0 2.91 0 100%
Mewbourne Energy Partners 95-B, L.P.(7) ............. 6 3 2.03 .74 73%
Mewbourne Energy Partners 96-A, L.P.(7) ............. 14 3 4.75 .73 87%
Mewbourne Energy Partners 97-A, L.P.(7) ............. 15 4 2.91 .70 81%
Mewbourne Energy Partners 98-A, L.P.(7) ............. 18 3 3.76 .60 86%
Mewbourne Energy Partners 99-A, L.P.(5)(7) .......... 11 1 4.37 .48 90%
----- ----- ----- ----- -----
Total ......................................... 122 20 32.92 4.28 88%
===== ===== ===== ===== =====
- ----------
(1) Gross wells include all wells in which investors owned a working
interest.
(2) Net wells is the total percentage of working interest owned by the
partnership in the wells.
(3) This partnership was terminated on November 30, 1994.
(4) The activities of this partnership consisted solely of exploratory
drilling.
(5) As of December 31, 1999, this partnership was engaged in drilling and
completion activities.
(6) This partnership was terminated September 1, 1996.
(7) This partnership is currently operating.
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70
PAYOUT AND NET CASH TABLES
The following tables provide information concerning the operating results
of partnerships sponsored by the managing partner or its affiliates.
PRIOR PERFORMANCE IS NOT INDICATIVE OF FUTURE RESULTS
INVESTORS' PAYOUT TABLE
December 31, 1999
Total Expenditures Revenues Before
Investors' Funds Including Operating Deducting Operating
Partnership Invested (1) Costs (2) Costs (3)
===================================================== ================ ==================== ====================
Mewbourne Oil, Ltd. 1977(4)(5) ......................... $ 2,643,700 $ 6,269,489 $ 6,527,236
Mewbourne Oil, Ltd. 1978A(4)(9) ........................ 3,121,150 1,961,733 22,575,395
Mewbourne Oil, Ltd. 1978B(4) (8) ....................... 3,247,534 12,719,565 13,452,048
Mewbourne Oil, Ltd. 1979(4)(5) ......................... 3,541,520 11,371,906 17,853,374
Mewbourne Oil, Ltd. 1980(4)(5)(6) ...................... 1,637,969 3,464,815 1,555,414
Mewbourne Development Partners 92 GP(9) ................ 1,049,800 1,626,902 1,094,167
Mewbourne Development Partners 93-A, L.P.(9) ........... 1,250,848 1,873,386 1,011,730
Mewbourne Development Partners 93-B, L.P.(9) ........... 1,175,725 1,903,870 1,186,410
Mewbourne Development Partners 94-A, L.P.(9) ........... 1,080,690 1,770,735 1,164,250
Mewbourne Development Partners 94-B, L.P.(9) ........... 914,151 1,671,775 1,396,574
Mewbourne Development Partners 94-C, L.P.(9) ........... 932,253 1,633,821 1,375,892
Mewbourne Energy Partners 1994 Private L.P.(9) ......... 1,470,000 1,751,131 876,456
Mewbourne Energy Partners 95-A, L.P.(9) ................ 1,619,000 2,373,558 2,413,873
Mewbourne Energy Partners 95-B, L.P.(9) ................ 2,011,000 2,540,078 797,831
Mewbourne Energy Partners 96-A, L.P. (9) ............... 3,872,000 5,190,027 2,498,329
Mewbourne Energy Partners 97-A, L.P.(9) ................ 3,141,000 4,416,577 2,524,713
Mewbourne Energy Partners 98-A, L.P.(7)(9) ............ 3,698,000 4,023,212 734,581
Mewbourne Energy Partners 99-A, L.P.(7)(9) ............. 5,727,000 3,701,986 0
- ------------
(1) Total subscriptions less organization, promotion, and, if applicable,
management fees.
(2) Includes total of all subscriptions, organization, promotion, and
management fees, drilling and completion costs, and operating costs.
Assumes all investors paid cash for their interests.
(3) Represents all oil and gas revenues credited to the investors net of
royalties and other burdens. Does not include interest or other income.
(4) The sharing of the partnership revenues and costs between the managing
partner and the investors was significantly different than the sharing of
the revenues and costs between the managing partner and the general and
limited partners in the partnership.
(5) This partnership was terminated on November 30, 1994.
(6) The activities of this partnership consisted solely of exploratory
drilling.
(7) As of December 31, 1999, this partnership was engaged in drilling and
completion activities.
(8) This partnership was terminated on September 1, 1996.
(9) This partnership is currently operating.
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71
PRIOR PERFORMANCE IS NOT INDICATIVE OF FUTURE RESULTS
INVESTORS' NET CASH TABLE
December 31, 1999
Total Expenditures Total Revenues After
Investors' Funds Net of Operating Deducting Operating Cash
Partnership Invested (1) Costs (2) Costs (3) Distributions(4)
----------- ---------------- ------------------ -------------------- ----------------
Mewbourne Oil, Ltd. 1977(5)(6) ..................... $ 2,643,700 $ 3,716,418 $ 3,974,165 $ 3,223,641(7)
Mewbourne Oil, Ltd. 1978A(5)(11) ................... 3,121,150 11,772,325 14,385,980 7,030,320(7)
Mewbourne Oil, Ltd. 1978B(5)(10) ................... 3,247,534 7,687,559 8,420,042 4,861,930(7)
Mewbourne Oil, Ltd. 1979(5)(6) ..................... 3,541,520 7,172,702 13,654,170 11,874,362(7)
Mewbourne Oil, Ltd. 1980(5)(6)(8) .................. 1,637,969 2,895,049 985,648 0(7)
Mewbourne Development Partners 92 GP(11) ........... 1,049,800 1,389,781 857,046 659,835(7)
Mewbourne Development Partners 93-A, L.P.(11) ...... 1,250,848 1,542,903 681,427 547,470(7)
Mewbourne Development Partners 93-B, L.P.(11) ...... 1,175,715 1,548,528 831,068 629,640(7)
Mewbourne Development Partners 94-A, L.P.(11) ...... 1,080,690 1,449,806 843,321 660,330(7)
Mewbourne Development Partners 94-B, L.P.(11) ...... 914,151 1,262,343 987,142 734,580(7)
Mewbourne Development Partners 94-C, L.P.(11) ...... 932,253 1,269,316 1,011,387 777,150(7)
Mewbourne Energy Partners 1994 Private L.P.(11) .... 1,470,000 1,540,503 665,828 600,930(7)
Mewbourne Energy Partners 95-A, L.P.(11) ........... 1,619,000 1,973,200 2,013,515 1,670,130(7)
Mewbourne Energy Partners 95-B, L.P.(11) ........... 2,011,000 2,233,742 491,495 375,210
Mewbourne Energy Partners 96-A, L.P.(11) ........... 3,872,000 4,535,819 1,844,119 1,376,100
Mewbourne Energy Partners 97-A, L.P.(11) ........... 3,141,000 3,986,979 2,095,115 1,575,090
Mewbourne Energy Partners 98-A, L.P.(9)(11) ....... 3,698,000 3,900,344 611,713 559,350
Mewbourne Energy Partners 99-A, L.P. (9)(11) ....... 5,727,000 3,687,227 (14,759) 0
- ----------
(1) Total subscriptions less organization, promotion, and management fees.
(2) Includes total of all subscription, organization, promotion, and
management fees, and drilling and completion costs.
(3) Represents all oil and gas revenues credited to the investors net of
royalties, other burdens and operating costs. Does not include interest
or other income.
(4) Net cash distributed to investors.
(5) The sharing of the partnership revenues and costs between the managing
partner and the investors was significantly different than the sharing
of the revenues and costs between the managing partner and the general
and limited partners in the partnership.
(6) This partnership was terminated on November 30, 1994.
(7) The 1977 partnership retained $553,549 of distributable operating cash
flow to reinvest in additional drilling. The 1978A, 1978B, 1979 and
1980 partnerships retained $1,836,329, $3,580,177, $2,326,134 and
$223,343 of distributable operating cash flow to reinvest in additional
drilling, respectively, and $5,391,821, $30,072, $125,133 and $732,939
of distributable operating cash flow was used to repay borrowings of
the partnership, respectively. The 92 GP, 93-A, 93-B, 94-A, 94-B, 94-C
and MEP 94-Private partnerships retained $64,165, $24,614, $76,838,
$82,864, $124,975, $111,208, $25,852, respectively of distributable
operating cash flow to complete drilling operations.
(8) The activities of this partnership consisted solely of exploratory
drilling.
(9) As of December 31, 1999, this partnership was engaged in drilling and
completion activities.
(10) This partnership was terminated on September 1, 1996.
(11) This partnership is currently operating.
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PRIOR PERFORMANCE IS NOT INDICATIVE OF FUTURE RESULTS
MANAGING PARTNER'S PAYOUT TABLE
December 31, 1999
Total Expenditures Including Revenues Before Deducting
Partnership Operating Costs (1) Operating Costs (2)
=============================================================== ============================ ==========================
Mewbourne Oil, Ltd. 1977(3)(4) .............................. $1,658,587 $2,293,090
Mewbourne Oil, Ltd. 1978A(3)(8) ............................. 6,073,181 7,881,827
Mewbourne Oil, Ltd. 1978B(3)(7) ............................. 3,732,499 4,975,412
Mewbourne Oil, Ltd. 1979(3)(4) .............................. 3,024,062 6,603,302
Mewbourne Oil, Ltd. 1980(3)(4)(5) ........................... 704,328 575,287
Mewbourne Development Partners 92 GP(8) ..................... 207,455 273,541
Mewbourne Development Partners 93-A, L.P.(8) ................ 258,069 252,931
Mewbourne Development Partners 93-B, L.P.(8) ................ 266,999 296,603
Mewbourne Development Partners 94-A, L.P.(8) ................ 246,721 291,063
Mewbourne Development Partners 94-B, L.P.(8) ................ 249,926 349,144
Mewbourne Development Partners 94-C, L.P.(8) ................ 239,359 343,974
Mewbourne Energy Partners 1994 Private L.P.(8) .............. 128,634 8,853
Mewbourne Energy Partners 95-A, L.P.(8) ..................... 142,962 360,694
Mewbourne Energy Partners 95-B, L.P.(8) ..................... 118,145 119,216
Mewbourne Energy Partners 96-A, L.P.(8) ..................... 258,476 373,314
Mewbourne Energy Partners 97-A, L.P.(8) ..................... 201,432 377,256
Mewbourne Energy Partners 98-A, L.P.(6)(8) .................. 140,087 109,765
Mewbourne Energy Partners 99-A, L.P.(6)(8) .................. 932,284 0
- -----------------
(1) Includes managing partner's share of drilling and completion costs.
(2) Represents all oil and gas revenues credited to the managing partner
net of royalties and other burdens. Does not include interest or other
income.
(3) The sharing of the partnership revenues and costs between the managing
partner and the investors was significantly different than the sharing
of the revenues and costs between the managing partner and the general
and limited partners in the partnership.
(4) This partnership was terminated on November 30, 1994.
(5) The activities of this partnership consisted solely of exploratory
drilling.
(6) As of December 31, 1999, this partnership was engaged in drilling and
completion activities.
(7) This partnership was terminated on September 1, 1996.
(8) This partnership is currently operating.
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PRIOR PERFORMANCE IS NOT INDICATIVE OF FUTURE RESULTS
MANAGING PARTNER'S NET CASH TABLE
December 31 1999
Total Revenues After
Total Expenditures Net Deducting Operating
Partnership of Operating Costs (1) Costs (2) Cash Distributions(3)
================================================== ===================== ====================== =====================
Mewbourne Oil, Ltd. 1977(4)(5) ..................... $ 762,173 $1,396,676 $1,137,362
Mewbourne Oil, Ltd. 1978A(4)(9) .................... 3,307,313 5,115,959 3,108,544
Mewbourne Oil, Ltd. 1978B(4)(8) .................... 1,871,615 3,114,528 1,890,870
Mewbourne Oil, Ltd. 1979(4)(5) ..................... 1,470,929 5,050,169 4,499,400
Mewbourne Oil, Ltd. 1980(4)(5)(6) .................. 493,595 364,554 0
Mewbourne Development Partners 92 GP(9) ............ 148,174 214,260 164,959
Mewbourne Development Partners 93-A, L.P.(9) ....... 175,446 170,308 136,867
Mewbourne Development Partners 93-B, L.P.(9) ....... 178,169 207,773 157,410
Mewbourne Development Partners 94-A, L.P.(9) ....... 166,472 210,814 165,082
Mewbourne Development Partners 94-B, L.P.(9) ....... 147,558 246,770 183,645
Mewbourne Development Partners 94-C, L.P.(9) ....... 148,233 252,848 194,287
Mewbourne Energy Partners 1994 Private L.P.(9) ..... 126,511 6,730 6,070
Mewbourne Energy Partners 95-A, L.P.(9) ............ 80,148 297,880 249,560
Mewbourne Energy Partners 95-B, L.P.(9) ............ 72,377 73,448 56,066
Mewbourne Energy Partners 96-A, L.P.(9) ............ 160,718 275,556 205,624
Mewbourne Energy Partners 97-A, L.P.(9) ............ 137,238 313,062 235,358
Mewbourne Energy Partners 98-A, L.P. (9) ........... 121,730 91,408 83,581
Mewbourne Energy Partners 99-A, L.P.(7)(9) ......... 922,455 (9,839) 0
- -----------------------
(1) Includes managing partner's share of drilling and completion costs,
exclusive of operating costs.
(2) Represents all oil and gas revenues credited to the managing partner
net of royalties, other burdens and operating costs. Does not include
interest or other income.
(3) Net cash distributed to managing partner. May include return of
capital.
(4) The sharing of the partnership revenues and costs between the managing
partner and the investors was significantly different than the sharing
of the revenues and costs between the managing partner and the general
and limited partners in the partnership.
(5) This partnership was terminated on November 30, 1994.
(6) The activities of this partnership consisted solely of exploratory
drilling.
(7) As of December 31, 1999, this partnership was engaged in drilling and
completion activities.
(8) This partnership was terminated on September 1, 1996.
(9) This partnership is currently operating.
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TAX DEDUCTIONS AND TAX CREDITS
The following two tables reflect the investors' share of the following
described partnerships' available tax deductions that were reported in the
partnerships' tax returns and such share of tax deductions as a percentage of
their subscriptions. The following percentages do not reflect the effect of the
revenues from the partnership's operations and are subject to audit adjustments
by the IRS. The following tables are based on past experience and should not be
considered as necessarily indicative of the results that may be expected from an
investment in a partnership. It is suggested that prospective subscribers
consult with their tax advisors concerning the tax benefits available to them
taking into account their individual tax circumstances. The tax benefits
available to each investor may vary materially depending upon their individual
tax circumstances.
PRIOR PERFORMANCE IS NOT INDICATIVE OF FUTURE RESULTS
CUMULATIVE TAX BENEFITS TO INVESTORS
PER $10,000 INVESTMENT
December 31, 1999
Aggregate Cumulative Tax Benefits
First Year Tax Deductions First Year Tax Through December 31,
Partnership Deductions (1) Thereafter (1) Benefits (2) 1999 (2)
=============================================== =============== ================ ============== =======================
Mewbourne Oil, Ltd. 1977(3) ..................... $2,902 $ 3,326 $2,031 $ 4,336
Mewbourne Oil, Ltd. 1978A(7) .................... 5,709 14,402 3,996 12,056
Mewbourne Oil, Ltd. 1978B(6) .................... 2,896 9,445 2,027 8,293
Mewbourne Oil, Ltd. 1979(3) ..................... 4,999 5,348 3,500 6,753
Mewbourne Oil, Ltd. 1980(3)(4) .................. 2,926 6,284 2,048 5,885
Mewbourne Development Partners 92 GP(7) ......... 1,964 5,384 609 2,741
Mewbourne Development Partners 93-A, L.P.(7) .... 4,228 2,214 1,674 2,551
Mewbourne Development Partners 93-B, L.P.(7) .... 2,321 4,538 919 2,716
Mewbourne Development Partners 94-A, L.P.(7) .... 6,065 1,412 2,402 2,961
Mewbourne Development Partners 94-B, L.P.(7) .... 5,523 1,849 2,187 2,919
Mewbourne Development Partners 94-C, L.P.(7) .... 4,955 2,252 1,962 2,853
Mewbourne Energy Partners 1994 Private L.P.(7)... 5,057 2,838 2,003 3,126
Mewbourne Energy Partners 95-A, L.P.(7) ......... 5,239 620 2,075 2,320
Mewbourne Energy Partners 95-B, L.P.(7) ......... 3,716 3,631 1,472 2,909
Mewbourne Energy Partners 96-A, L.P.(7) ......... 3,479 3,018 1,378 2,573
Mewbourne Energy Partners 97-A, L.P.(7) ......... 3,781 3,671 1,497 2,950
Mewbourne Energy Partners 98-A, L.P.(7) ......... 2,867 3,111 1,135 2,307
Mewbourne Energy Partners 99-A, L.P.(5)(7) ...... 4,961 0 1,935 1,935
- ----------
(1) Tax deductions include Non-Capital Expenditures.
(2) Tax benefits are tax deductions multiplied by the respective year's
maximum individual tax rate.
(3) This partnership was terminated on November 30, 1994.
(4) The activities of this partnership consisted solely of exploratory
drilling.
(5) As of December 31, 1999, this partnership was engaged in drilling and
completion activities.
(6) This partnership was terminated on September 1, 1996.
(7) This partnership is currently operating.
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PRIOR PERFORMANCE IS NOT INDICATIVE OF FUTURE RESULTS
CASH DISTRIBUTIONS AND TAX BENEFITS
AS A PERCENT OF TOTAL SUBSCRIPTIONS
December 31, 1999
(Investors' share only)
Cash
Partnership Distributions (1) Tax Benefits (2) Total Return (3)
=========================================================== ==================== ================== ==================
Mewbourne Oil, Ltd. 1977(4)(5) ................... 111.5%(6) 43.3% 154.9%
Mewbourne Oil, Ltd. 1978A(4)(10) ................. 203.4%(6) 120.6% 324.0%
Mewbourne Oil, Ltd. 1978B(4)(9) .................. 135.8%(6) 82.9% 218.7%
Mewbourne Oil, Ltd. 1979(4)(5) ................... 304%(6) 67.5% 371.5%
Mewbourne Oil, Ltd. 1980(4)(5)(7) ................ 0.0%(6) 58.9% 58.9%
Mewbourne Development Partners 92 GP(10) ......... 56.9%(6) 27.4% 83.8%
Mewbourne Development Partners 93-A, L.P.(10) .... 39.6%(6) 25.5% 65.1%
Mewbourne Development Partners 93-B, L.P.(10) .... 48.5%(6) 27.2% 75.6%
Mewbourne Development Partners 94-A, L.P.(10) .... 55.3%(6) 29.6% 84.9%
Mewbourne Partners 94-B, L.P.(10) ................ 72.7%(6) 29.2% 101.9%
Mewbourne Development Partners 94-C, L.P.(10) .... 75.5%(6) 28.5% 104.0%
Mewbourne Energy Partners 1994 Private L.P.(10)... 40.9%(6) 31.3% 72.1%
Mewbourne Energy Partners 95-A, L.P.(10) ......... 103.2%(6) 23.2% 126.4%
Mewbourne Energy Partners 95-B, L.P.(10) ......... 18.7%(6) 29.1% 47.8%
Mewbourne Energy Partners 96-A, L.P.(10) ......... 35.5%(6) 25.7% 61.3%
Mewbourne Energy Partners 97-A, L.P.(10) ......... 50.2%(6) 29.5% 79.7%
Mewbourne Energy Partners 98-A, L.P.(10) ......... 15.1% 23.7% 38.8%
Mewbourne Energy Partners 99-A, L.P.(8)(10) ...... 0.0% 19.4% 19.4%
- ------------------------
(1) Represents total cash distributions made to partners divided by total
funds invested by partners. The first 100% of cash distributions made
to partners represents a return of capital.
(2) Total tax benefits divided by total funds invested by partners. This
table assumes investors were able to fully utilize all tax benefits at
the maximum marginal federal rate.
(3) Sum of (1) and (2).
(4) The sharing of the partnership revenues and costs between the managing
partner and the investors was significantly different than the sharing
of the revenues and costs between the managing partner and the general
and limited partners in the partnership.
(5) This partnership was terminated on November 30, 1994.
(6) The 1977 partnership retained $553,549 of distributable operating cash
flow to reinvest in additional drilling. The 1978A, 1978B, 1979 and
1980 partnerships retained $1,836,329, $3,580,177, $2,326,134 and
$223,343 of distributable operating cash flow to reinvest in additional
drilling, respectively, and $5,391,821, $30,072, $125,133 and $732,939
of distributable operating cash flow was used to repay borrowings of
the partnership, respectively. The 92 GP, 93-A, 93-B, 94-A, 94-B, 94-C
and MEP 94-Private partnerships retained $65,165, $24,614, $76,838,
$82,864, $124,975, $111,208, and $25,852, respectively of distributable
operating cash flow to complete drilling operations.
(7) The activities of this partnership consisted solely of exploratory
drilling.
(8) As of December 31, 1999, this partnership was engaged in drilling and
completion activities.
(9) This partnership was terminated on September 1, 1996.
(10) This partnership is currently operating.
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RESERVES AND FUTURE NET REVENUES OF PRIOR PROGRAMS
The following table summarizes as of December 31, 1999, the estimates
of the proved developed reserves of Mewbourne Development Partners 92 GP,
Mewbourne Development Partners 93-A, L.P., Mewbourne Development Partners 93-B,
L.P., Mewbourne Development Partners 94-A, L.P., Mewbourne Development Partners
94-B, L.P., Mewbourne Development Partners 94-C, L.P., Mewbourne Energy Partners
95-A, L.P., Mewbourne Energy Partners 95-B, L.P., Mewbourne Energy Partners
96-A, L.P., Mewbourne Energy Partners 97-A, L.P., Mewbourne Energy Partners
98-A, L.P. and Mewbourne Energy Partners 94 Private, the future net revenues
attributable to such reserves, and the present value of such future net revenues
based on a constant unescalated price of oil and gas and discounted at 10% per
annum. The following table also summarizes as of December 31, 1999, the
estimates of the proved undeveloped reserves of Mewbourne Energy Partners 95-B,
L.P., Mewbourne Energy Partners 96-A, L.P., Mewbourne Energy Partners 97-A,
L.P., and Mewbourne Energy Partners 98-A, L.P., the future net revenues
attributable to such reserves, and the present value of such future net revenues
based on a constant unescalated price of oil and gas and discounted at 10% per
annum. Such information was prepared, as of December 31, 1999, by Forrest A.
Garb & Associates, Inc., the partnerships' independent expert. Current reserve
information is not maintained by the managing partner or its affiliates for the
five private limited partnerships sponsored during the years 1977 through 1980
and therefore the reserves of such partnerships is not included in the following
table. Likewise, insufficient reserve information currently exists for Mewbourne
Energy Partners 99-A, L.P., which is currently engaged in drilling and
completion activities, for the reserves of that partnership to be included in
the following table.
THE RESULTS OF PRIOR OPERATIONS SHOULD NOT BE CONSTRUED AS BEING
INDICATIVE OF THE RESULTS TO BE EXPECTED FROM AN INVESTMENT IN A PARTNERSHIP OR
QUANTITIES OF OIL AND GAS WHICH MAY BE DERIVED FROM WELLS TO BE DRILLED BY A
PARTNERSHIP, BUT MERELY SERVE AS ESTIMATES OF PROVED RESERVES FOR A PRIOR
PROGRAM, THE ESTIMATED FUTURE NET REVENUES OF SUCH PROGRAM BASED ON SUCH
RESERVES AND THE PRESENT VALUE OF THE ESTIMATED DISCOUNTED FUTURE NET REVENUES
OF SUCH PROGRAM.
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PRIOR PERFORMANCE IS NOT INDICATIVE OF FUTURE RESULTS
PROVED RESERVES AND FUTURE NET REVENUES
AS OF DECEMBER 31, 1999
- --------------------------------------------------------------------------------
Present
Value
Net Oil Net Gas Estimated Discounted
Category of Proved Reserves Reserves Future Net at 10% Per
Partnership Reserves (BBLS) (MCF) Revenues Annum
- --------------------------------------- ------------------ ----------- ----------- ----------- ----------
Mewbourne Development Partners 92 GP (1)....... Proved Developed 770 41,019 48,823 41,429
Mewbourne Development Partners 93-A, L.P. (1).. Proved Developed 4,988 348,183 339,961 210,129
Mewbourne Development Partners 93-B, L.P. (1).. Proved Developed 23,009 445,766 712,749 403,168
Mewbourne Development Partners 94-A, L.P. (1).. Proved Developed 39,658 402,819 938,716 508,672
Mewbourne Development Partners 94-B, L.P. (1).. Proved Developed 61,731 414,141 1,387,502 742,770
Mewbourne Development Partners 94-C, L.P. (1).. Proved Developed 45,064 393,636 1,142,607 651,401
Mewbourne Energy Partners 94 Private L.P. (1).. Proved Developed 10,371 954,622 1,081,172 572,010
Mewbourne Energy Partners 95-A, L.P. (2)....... Proved Developed 36,723 849,443 1,460,884 835,662
Mewbourne Energy Partners 95-B, L.P. (2)....... Proved Developed 12,682 477,227 523,898 310,832
Proved Undeveloped 146 24,458 56,658 23,515
Total Proved (3) 12,828 501,685 580,556 334,347
Mewbourne Energy Partners 96-A, L.P. (2)....... Proved Developed 22,834 2,055,171 2,935,117 1,680,462
Proved Undeveloped 1,190 197,860 201,414 103,553
Total Proved (3) 24,024 2,253,031 3,136,531 1,784,015
Mewbourne Energy Partners 97-A, L.P. (2)....... Proved Developed 4,699 2,162,975 2,537,220 1,455,121
Mewbourne Energy Partners 98-A, L.P. (2)....... Proved Developed 19,622 3,358,413 5,167,622 3,322,018
Proved Undeveloped 0 489,068 622,511 297,541
Total Proved (3) 19,622 3,847,481 5,790,133 3,619,559
- --------------------
(1) Includes the partnership's 80.808081% ownership interest and the
managing partner's 19.191919% ownership interest arising under drilling
program agreement between the managing partner and such partnership.
(2) Includes the partnership's 87.878788% ownership interest and the
managing partner's 12.121212% ownership interest arising under the
drilling program agreement between the managing partner and such
partnership.
(3) Total proved reserves is the sum of proved developed reserves and
proved undeveloped reserves.
Reserve estimates and future net cash flow attributable to such
reserves were prepared using an unescalated price for oil and gas. The price
used was the price being received as of December 31, 1999 which on a weighted
average basis was $25.03 per barrel of oil and $2.18 per mcf of gas. In arriving
at estimated future net revenues, lease operating costs (including overhead
charges under operating agreements), transportation costs, costs of producing,
severance taxes, ad valorem taxes and estimated future capital expenditures were
deducted from revenue anticipated to be received and were not increased to
reflect the anticipated effects of inflation. No deduction was made for
partnership or program overhead expenses, federal income taxes, depletion,
depreciation or amortization or other indirect costs.
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78
There are numerous uncertainties inherent in estimating quantities of
proved reserves and in projecting the future rates of production and the timing
of development expenditures. The reserve data represents estimates only.
Estimates of economically recoverable oil and gas reserves and of the future net
revenues from such reserves are based on a number of factors and assumptions,
such as historical production of the properties as compared with similar
producing properties, the assumed effects of regulation by governmental
agencies, taxes, development costs and workover and remedial costs, all of which
may vary considerably from actual results.
FOR THE FOREGOING REASONS, ESTIMATES OF THE ECONOMICALLY RECOVERABLE
RESERVES OF OIL AND GAS ATTRIBUTABLE TO ANY PARTICULAR GROUP OF PROPERTIES, THE
CLASSIFICATION OF SUCH RESERVES AND ESTIMATES OF THE FUTURE NET REVENUES
EXPECTED THEREFROM, PREPARED AT DIFFERENT TIMES OR PREPARED BY DIFFERENT
ENGINEERS, MAY VARY CONSIDERABLY. THE FUTURE NET REVENUES SHOWN ON THE TABLE SET
FORTH ABOVE SHOULD NOT BE TAKEN AS THE FAIR MARKET VALUE OF THE ESTIMATED OIL
AND GAS RESERVES.
TAX ASPECTS
The following discussion is a general summary only of the United States
federal income and various other tax aspects of partnerships engaged in oil and
gas operations and the tax effects on their partners. It is impractical to
comment on all of the tax consequences of an investment in a partnership or of
the contemplated operations of the partnerships and the drilling programs. Such
consequences may vary depending on an investor partner's particular
circumstances. The discussion is directed primarily to individuals who are
citizens of the United States. Persons who are not individual U.S. citizens,
such as partnerships, corporations, trusts, estates, or tax-exempt entities,
including a pension, profit-sharing, or stock bonus plan, Keogh plan, IRA, or
other qualified employee benefit plan, or ERISA plan, may have federal income
tax consequences substantially different from those discussed below. A
particular investor may be subject to various facts and circumstances that are
applicable only to him and that may give rise to additional considerations. The
following discussion generally does not address any of those additional
considerations. In addition, an investment in interests may have state and local
tax consequences to a particular investor that are not discussed below.
Accordingly, each potential investor is urged to consult his tax advisor prior
to purchasing interests, with specific reference to the effect of his particular
facts and circumstances on the matters discussed in this prospectus. See "--
General Tax Provisions" and "Terms of the Offering -- Suitability Standards."
The tax considerations and opinions of counsel discussed herein are
based on existing provisions of the Internal Revenue Code, existing Treasury
Regulations, published interpretations of the Internal Revenue Code and such
regulations by the IRS and existing court decisions, any of which could be
changed or become inapplicable at any time. Any new legislation, judicial
decisions, regulations, or other pronouncements may apply retroactively to
transactions prior to the date of such changes and could significantly modify
the statements made and tax considerations discussed in this prospectus.
A portion of the following discussion focuses on the characterization
of income or losses under various rules as ordinary income or loss or capital
gain or loss. At the present time, the marginal rate of federal income tax
applicable to long-term capital gains may be significantly more favorable for an
individual taxpayer, depending upon income level, than the rate on ordinary
income. Corporations, on the other hand, are taxable at the same rate on
ordinary income and capital gains.
OPINION OF COUNSEL
Vinson & Elkins L.L.P., counsel to the managing partner, has rendered
an opinion that addresses the material federal income tax consequences of an
investment in interests from the perspective of an individual investor who is a
U.S. citizen. The opinion of counsel states the following conclusions:
o At the time of its formation, a partnership and the related
drilling program will each be classified as a partnership for
federal income tax purposes.
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79
o A partnership will not be classified as a corporation under
the "publicly traded partnership" rules of Section 7704 of the
Code.
o Except as noted below, the allocation of income, gains,
losses, and deductions between the general and limited
partners and the managing partner under the partnership
agreement, and between a partnership and the managing partner
as participants in the related drilling program and Mewbourne
Oil Company as drilling program manager under the drilling
program agreement, will be respected for federal income tax
purposes.
o The allocation provisions of the partnership agreement and the
program agreement should be in compliance with Section 704(c)
of the Code with respect to property contributed to a drilling
program by the managing partner.
o The passive activity loss limitations of Section 469 of the
Code will not limit deductions available to a general partner
in a partnership, prior to any conversion of his general
partner interest in the partnership to a limited partner
interest, in respect of the partnership's drilling and
operation of wells under working interests.
o A partnership will not be treated as a "publicly traded
partnership" for purposes of the application of the passive
activity loss limitations of Section 469 of the Code.
o The conversion of a general partner interest to a limited
partner interest will be nontaxable, provided, however, that
any reduction in a partner's share of partnership debt
resulting from such conversion will be treated as a cash
distribution which could result in recognition of income.
For the reasons hereinafter described, counsel is unable to render an
opinion with respect to the following specific federal income tax issues:
o The validity of any special allocation of an item that is
dependent on a partner's basis in an oil and gas property (see
"-- Partnership Taxation -- Allocations").
o The amount, if any, of the organization and offering expenses
that will be deductible or amortizable (see "-- Partnership
Taxation -- Organization and Offering Expenses Sale
Commissions and Due Diligence Fees").
o The amount, if any, of the initial administrative costs that
will be deductible or amortizable (see "-- Partnership
Taxation -- Management Fee," --Partnership Taxation --
Administrative Costs").
o The deductibility in a given year of any intangible drilling
costs incurred in a year prior to the drilling of the wells to
which such costs relate (see "-- Special Features of Oil and
Gas Taxation -- Intangible Drilling Costs").
o The availability or extent of percentage depletion deductions
to the partners (see "-- Special Features of Oil and Gas
Taxation -- Depletion").
o Whether interests will be considered "publicly offered
securities" for purposes of ERISA (see "-- General Tax
Provisions -- Investment by Tax-Exempt Entities").
Although counsel is unable to render an opinion as to the issues
described above, the discussion of federal income tax consequences set forth in
this prospectus under the headings "Risk Factors -- Tax Risks" and "Tax Aspects"
has been reviewed by counsel and, to the extent such discussion involves matters
of law, counsel is of the opinion that such discussion is accurate in all
material respects under the Code, the Treasury Regulations promulgated
thereunder and existing interpretations of such regulations and addresses fairly
the principal aspects of each material federal income tax issue relating to an
investment in interests by an individual citizen of the United
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80
States. Finally, in light of the various opinions and assumptions described
above, but subject to the qualifications and limitations placed thereon, counsel
is of the opinion that the material federal income tax benefits of an investment
in interests, in the aggregate, more likely than not will be realized in
substantial part by an investor partner who acquires his interests for profit,
provided that an investor partner who acquires limited partner interests either
is not subject to the passive activity loss limitations of Section 469 of the
Code or has sufficient passive income against which he can deduct his share of
any partnership deductions and losses. For a discussion of the timing of the
realization of such tax benefits, see "-- Special Features of Oil and Gas
Taxation -- Basis and At Risk Limitations."
The opinion of counsel is based on the facts described in this
prospectus and on representations made by the managing partner, which
representations are described in the following discussion. Any alterations of
the facts or representations may adversely affect the opinion rendered. An
opinion of counsel is not binding on the IRS. No rulings will be requested from
the IRS with respect to the tax consequences of ownership of interests in a
partnership, and no assurance can be given that the opinion expressed by counsel
herein would, if challenged, be sustained by a court, or that legislation,
judicial decision or administrative interpretation may not significantly modify
the conclusions expressed in such opinions.
Counsel has expressed no opinion with respect to the amount of
allowable deductions or losses that may be generated by a partnership, the
actual amount of an investor partner's share of allowable deductions or losses
from the activities of a partnership, the amount, if any, of taxable income that
may be generated by a partnership or the relationship between any such taxable
income and any distributions which may be made by a partnership.
EACH PROSPECTIVE INVESTOR PARTNER IS ADVISED TO CONSULT HIS TAX ADVISOR
WITH RESPECT TO THE UNITED STATES FEDERAL AND STATE INCOME TAX CONSEQUENCES OF
PARTICIPATION IN A PARTNERSHIP.
EXCEPT AS EXPRESSLY PROVIDED OTHERWISE, THE FOLLOWING DISCUSSION
RELATES TO THE PARTNERSHIPS AND THE DRILLING PROGRAMS SEPARATELY.
PARTNERSHIP TAXATION
General. A partnership is not a taxable entity under federal income tax
laws. Instead, each partner reports on his federal income tax return for the
taxable year in which the partnership's taxable year ends his distributive share
of the income, gains, losses, deductions, and credits of the partnership,
irrespective of any actual cash distributions made to such partner during his
taxable year. For example, a partner will be required to report his share of
partnership income as determined under the partnership's method of accounting,
notwithstanding that the revenues resulting in such income are retained in whole
or in part by the partnership for payment of any partnership expenses or debt
service or for working capital. A partner's share of any partnership losses in a
taxable year may be applied against his income from other sources only to the
extent of the tax basis of his interest in the partnership and to the extent
permitted under the "passive activity" and "at risk" limitations. See "--
Special Features of Oil and Gas Taxation -- Passive Activity Loss Limitations"
and "-- Special Features of Oil and Gas Taxation -- Basis and At Risk
Limitations."
Partnership Classification. Each partnership will invest in the related
drilling program, which will be a joint operation of that partnership, the
managing partner and the drilling program manager. Each drilling program is
intended to constitute a partnership for tax purposes only; it is not intended
to be a partnership under state law and will not be subject to state law
provisions comparable to those applicable to the partnerships. Expected tax
consequences resulting from an investment in interests are dependent upon the
classification of the partnerships and the drilling programs as partnerships for
federal income tax purposes. The expenditures made and income received by a
drilling program will, if the drilling program is classified as a partnership
for federal income tax purposes, flow through to the related partnership and, if
the partnership is classified as a partnership for federal income tax purposes,
ultimately to the partners in amounts equal to their respective distributive
shares of income, gain, loss, deduction and credit. In order for the anticipated
tax consequences of an investment in interests to materialize, however, the
partnerships and the drilling programs must be classified as partnerships for
federal income tax purposes and not as associations or "publicly traded
partnerships" taxable as corporations. Any references in the following
discussion to
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partnerships relate only to organizations treated as partnerships for federal
income tax purposes and do not imply that the drilling program is a partnership
for any other purpose.
Treasury Regulations under Section 7701 of the Code provide that a
domestic business entity other than a "corporation," including a "publicly
traded partnership," may elect whether to be treated as a partnership or an
association (taxable at a corporation) for federal income tax purposes. Treasury
Regulation Section 301.7701-2 defines "corporations" to include corporations
denominated as such under applicable law, associations, joint stock companies,
insurance companies and other entities distinguishable from the partnerships and
the drilling programs. Under a default rule in the Treasury Regulations,
partnerships formed under a state statute, such as the partnerships, and joint
ventures, such as the drilling programs, are treated as partnerships for federal
income tax purposes, unless such entities affirmatively elect to be treated as
associations taxable as corporations. The partnerships and the drilling programs
will not elect to be treated as associations taxable as corporations for federal
income tax purposes.
Counsel to the managing partner is of the opinion that, at the time of
formation, each partnership and each drilling program will be treated as a
partnership for federal income tax purposes. Such opinion is based on the
following representations made by the managing partner:
o A partnership will be organized and operated in accordance
with all applicable state statutes and the partnership
agreement and the related drilling program will be organized
and operated in accordance with all applicable state statutes
and the drilling program agreement.
o No participant in a drilling program will elect to be excluded
from the provisions of Subchapter K of Chapter 1 of Subtitle A
of the Internal Revenue Code.
o The partnerships and the drilling programs will not elect to
be treated as corporations under the Section 7701 Treasury
Regulations.
No assurance can be given that a partnership or a drilling program will
not lose partnership status as a result of future changes in the law, or other
facts upon which the opinion of counsel is based.
The classification of a partnership or a drilling program as an
association taxable as a corporation for federal income tax purposes would have
a material adverse effect on the general and limited partners. If a drilling
program were determined to be taxable as a corporation, its income, deductions,
and credits would be reported by the drilling program and not its participants,
including the partnership, and the drilling program would be taxed directly on
its taxable income. Distributions by that drilling program to the related
partnership would be treated as taxable dividends to the extent of current and
accumulated earnings and profits of the drilling program. If a partnership were
determined to be taxable as a corporation, its income, deductions, and credits
would be reported by the partnership and not by its general and limited
partners, the partnership would be taxed directly on any net income, and
distributions to its general and limited partners would be treated as taxable
dividends to the extent of current and accumulated earnings and profits of the
partnership. Thus, any tax benefits anticipated from investment in a partnership
would be adversely affected or eliminated if either the partnership or the
related drilling program were treated as a corporation.
Section 7704 of the Internal Revenue Code treats certain "publicly
traded partnerships" as corporations for federal income tax purposes. Section
7704 defines a publicly traded partnership as a partnership in which the
partnership interests are traded on an established securities market or are
readily tradable on a secondary market or the substantial equivalent of a
secondary market. The rule taxing publicly traded partnerships as corporations,
however, is specifically inapplicable to a partnership for any year if at least
90% of the partnership gross income for such year and all preceding years
consists of, among other things, interest or income from the exploration,
development, production, processing, refining, transportation, or marketing of
oil and gas and gains from the sale of assets used to generate that income.
Counsel to the managing partner is of the opinion that neither partnership will
be taxable as a corporation under the "publicly traded partnership" rules of
Section 7704 of the Internal Revenue Code. Such opinion is based on the
following representations made by the managing partner:
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o At least 90% of the gross income of each partnership in each
taxable year will consist of interest or income from the
exploration, development, production, processing, refining,
transportation, or marketing of oil and gas or gains from the
sale of assets used to generate that income.
o The managing partner does not plan to list interests with, or
trade interests on, an established securities exchange or to
itself make a secondary market in interests.
o The sum of the percentage interests in the capital or profits
of a partnership sold or otherwise disposed of, including
redemptions or repurchases other than repurchases made
pursuant to the right of presentment, during any taxable year
will not exceed 2% of the total interests in the partnership's
capital or profits.
o The managing partner is not aware of any current public or
secondary market, or substantial equivalent of such a market,
for interests and does not anticipate that any such market
will develop.
o The managing partner will enforce the restriction on transfers
in the partnership agreement to prevent the partnership from
qualifying as a "publicly traded partnership."
Such opinion is not binding on the IRS, and there can be no assurance that the
IRS will not assert that a partnership is a "publicly traded partnership"
subject to treatment as a corporation under Section 7704 of the Internal Revenue
Code.
THE FOLLOWING DISCUSSION IS PREDICATED ON THE ASSUMPTION THAT THE
PARTNERSHIPS AND THE DRILLING PROGRAMS WILL BE CLASSIFIED AS PARTNERSHIPS FOR
FEDERAL INCOME TAX PURPOSES AND WILL NOT BE CLASSIFIED AS "PUBLICLY TRADED
PARTNERSHIPS."
Taxation of Partners. For each taxable year, each investor partner will
be required to report on his individual federal income tax return his share of
partnership income, gain, loss, deduction, and credit for such taxable year.
Each investor partner is required to take his share into account in computing
his federal income tax liability regardless of whether he has received or will
receive any cash distributions from a partnership. Therefore, he may be required
to report and pay tax on income that the partnership has earned but that has not
been distributed to him. This may occur, for example, when a partnership uses
revenues to repay partnership borrowings or to pay nondeductible expenditures.
A distribution of cash to an investor partner generally is not taxable
to such investor partner unless the amount of the distribution exceeds the
investor partner's basis in his interests. Any such excess generally should be
taxable as capital gain, assuming those interests are held as a capital asset.
If, however, any portion of the distribution is considered to be in exchange for
the investor partner's interest in ordinary income items, including potential
recapture of intangible drilling cost, depletion, and depreciation deductions,
that portion will be taxed as ordinary income even if the amount of the
distribution did not exceed the investor partner's tax basis in his interests.
In addition, an investor partner could recognize income if cash distributions
made to him cause his at risk amount to be reduced below zero. See "Tax Aspects
- -- Special Features of Oil & Gas Taxation -- Basis and At Risk Limitations."
The partnerships and the drilling programs will use the calendar year
and the accrual method of accounting for federal income tax purposes. The IRS,
however, could require a partnership or a drilling program to treat particular
items of income, gain, loss, or deduction under a different method of accounting
if it determines that the use of the accrual method with respect to that item
does not clearly reflect income. A change in the method of accounting could
defer deductions or accelerate income.
Allocations. Under the partnership agreement, all items of partnership
income, gain, loss, deduction, and credit are allocated 100% to the general and
limited partners and 0% to the managing partner.
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Each partnership and the related drilling program will maintain a
capital account for each partner or participant in the drilling program which
will be credited (increased) by his or its contributions to the partnership or
drilling program and all items of income and gain allocated to such partner or
participant. Such capital account will be debited (reduced) by all distributions
and all deductions and losses allocated to such partner or participant. On
dissolution and liquidation of a partnership or drilling program, each partner
or participant will be entitled, after payment or provision for debts and
liabilities and adjustment of the partners' or participants' capital accounts
for any unrealized gain or loss in properties to be distributed in kind, to
receive assets equal in value to his or its respective positive capital account
balance, if any, as so adjusted.
Partners are not obligated to restore deficit capital account balances
following the liquidation of their respective interests in a partnership. As
discussed under "Participation in Costs and Revenues," the partnership agreement
provides for modifications in the allocations described above if necessary to
prevent or eliminate any deficit capital account balance for any partner, taking
into account reasonably expected deductions and distributions in subsequent
years.
The manner in which the drilling program agreement allocates among the
participants therein items of cost and revenue and items of income, gain, loss,
deduction, and credit for income tax purposes is discussed under "Participation
in Costs and Revenues." The drilling program agreement requires any participant
with a deficit capital account balance following the distribution of liquidation
proceeds to restore such deficit to the drilling program..
Partnership allocations of income, gain, loss, deduction, and credit
among partners are governed generally by Section 704(b) of the Internal Revenue
Code. Section 704(b) provides that partnership allocations will be recognized
for federal income tax purposes if such allocations either have "substantial
economic effect" or are made, or deemed made, in accordance with the partners'
respective interests in the partnership, determined by taking into account all
relevant facts and circumstances. If an allocation of an item does not have
substantial economic effect, such item will be reallocated among the partners in
accordance with their interests in the partnership.
Treasury Regulations section 1.704-1(b) indicates that allocations will
have economic effect if, throughout the term of the partnership:
(a) they are reflected in the partners' capital accounts,
(b) such capital accounts are respected upon liquidation of
the partnership, and
(c) a partner with a deficit in his capital account following
the distribution of liquidation proceeds is required to restore the
amount of such deficit to the partnership.
If requirements (a) and (b) are satisfied, but requirement (c) is not,
an allocation may nevertheless be considered to have economic effect if the
allocation does not cause or increase a deficit in the recipient partner's
capital account balance, determined after taking into account certain reasonably
anticipated deductions and distributions, and the partnership agreement contains
a "qualified income offset" which provides that a partner who unexpectedly
receives an adjustment, allocation or distribution which causes or increases a
deficit balance will be allocated items of income and gain in an amount and
manner sufficient to eliminate such deficit balance as quickly as possible.
Since:
o the allocations of items of income, gain, loss, and deduction
under the partnership agreement and the drilling program
agreement are reflected in the partners' and participants'
capital accounts,
o those capital accounts will be recognized upon liquidation of
a partnership,
o the drilling program agreement requires a participant with a
deficit capital account balance after the distribution of
liquidation proceeds to restore the amount of such deficit to
the drilling program,
o the partnership agreement contains a "qualified income offset"
provision, and
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o the allocations in the partnership agreement and the program
agreement should have economic effect under Section 704(b).
The economic effect of an allocation will be "substantial" if there is
a reasonable possibility that the allocation will substantially affect the
dollar amounts to be received by the partners from the partnership, independent
of tax consequences.
Although the determination of whether economic effect is "substantial"
is a question of fact which may depend in part on the timing of income and
deductions and on consideration of the partners' and participants'
nonpartnership tax attributes, under present facts and circumstances, and except
as noted below, the economic effect of the allocations under the partnership
agreement and the drilling program agreement should be considered to be
substantial under Section 704(b) and regulations promulgated thereunder.
Counsel to the managing partner is of the opinion that, except as
discussed in the previous paragraph and below, the allocation of income, gains,
losses, and deductions between the general and limited partners and the managing
partner under the partnership agreement and between a partnership and as
participants under the drilling program agreement will be recognized for federal
income tax purposes.
Under Section 704(c) of the Internal Revenue Code, income, gain, loss,
and deduction with respect to property contributed to a partnership by a partner
must be shared among its partners in a manner that takes into account the
variation between the partnership's adjusted tax basis in such property and the
fair market value of the property at the time of contribution. It is not
expected that property will be contributed to a partnership by an investor
partner but property will be contributed to the drilling program by the managing
partner. Under the drilling program agreement, the adjusted tax basis with
respect to such contributed property will be allocated to the managing partner
and only the managing partner will be entitled to claim cost depletion with
respect to such property. Accordingly, counsel to the managing partner is of the
opinion that the allocation provisions of the partnership agreement and the
drilling program agreement should be in compliance with Section 704(c) with
respect to property contributed or deemed contributed to a partnership or a
drilling program.
Elections and Returns. Each partnership and each drilling program will
be subject to the partnership provisions of the Internal Revenue Code and to
similar provisions of any applicable state income tax laws. Each partnership and
each drilling program will adopt the accrual method of accounting and calendar
year as its taxable year for income tax purposes. By March 15 of each year or as
soon thereafter as reasonably possible, each investor partner will receive a
report showing his distributive share of items of income, gain, loss, deduction,
and credit for the preceding year.
While no federal income tax is required to be paid by an organization
classified as a partnership for federal income tax purposes, a partnership must
file federal income tax information returns which are subject to audit by the
IRS. Any such audit may lead to adjustments, in which event the general and
limited partners may be required to file amended personal federal income tax
returns. Any such audit also may lead to an audit of an investor partner's
individual tax return and adjustments to items unrelated to an investment in
interests.
Determinations of Partnership Items at Partnership Level. For purposes
of reporting, audit, and assessment of additional federal income tax, the tax
treatment of "partnership items" is determined at the partnership level. Each
partner must report such items on his individual tax return in a manner
consistent with the partnership determination. The IRS generally cannot initiate
deficiency proceedings against an individual partner with respect to partnership
items without first conducting an administrative proceeding at the partnership
level as to the correctness of the partnership's treatment of the item. An
individual partner may not file suit for a credit or a refund arising out of a
partnership item without first filing a request for an administrative proceeding
by the IRS at the partnership level. Individual partners are entitled to notice
of such administrative proceedings and decisions made at such proceedings,
except in the case of partners with less than a 1% profits interest in a
partnership having more than 100 partners. If a group of partners having an
aggregate profits interest of 5% or more in such a partnership so requests,
however, the IRS also must mail notices to a partner appointed by that group to
receive notice. All general and limited partners, whether or not entitled to
notice, are entitled to participate in the administrative proceedings at the
partnership level,
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although the partnership agreement provides for waiver of certain of these
rights by the general and limited partners. All general and limited partners in
a partnership, including those not entitled to notice, may be bound by a
settlement reached by the partnership's "tax matters partner," which will be the
managing partner. If a proposed tax deficiency is contested in any court by any
investor partner of a partnership or by the managing partner, all general and
limited partners of that partnership may be deemed parties to such litigation
and bound by the result reached therein.
Administrative Costs. The managing partner intends generally to take
the position that administrative costs reimbursed to the managing partner or the
drilling program manager by a partnership are deductible in the year of payment.
To the extent that administrative costs are determined to constitute an
organization or syndication cost or some other nondeductible cost, such amount
will not give rise to any deduction in the year of payment but, rather, will be
deductible (if at all) only over some period of time. The determination of the
portion (if any) of the Administrative Cost that is deductible and the timing of
any such deduction are factual issues. Therefore, counsel to the managing
partner is unable to render any opinion as to the amount, if any, of the
Administrative Cost reimbursement that will be deductible or amortizable.
Conversion of General Partner Interests. As discussed under "Terms of
the Offering -- Conversion of General Partner Interests," the general partner
interests in a partnership may be converted to limited partner interests
following the completion of the partnership's drilling activities. Such
conversion will not constitute a sale or exchange. Accordingly, a partner will
not recognize any gain or loss as a result of a conversion of a general partner
interest in a partnership into a limited partner interest in the partnership,
unless the converting general partner's relative share of any partnership
liabilities is reduced as a result of such conversion. Such a reduction would be
treated as a constructive distribution of cash to that general partner, which
would reduce the basis of his interests and would be taxable to the extent it
exceeds his basis or at risk amount. See "Tax Aspects -- Special Features of
Partnership Taxation -- Basis and At Risk Limitations."
A partnership will constructively terminate for federal income tax
purposes if 50% or more of the interests in profits and capital of the
partnership are sold or exchanged in any consecutive 12-month period. The IRS
has ruled that a conversion of a general partner interest to a limited partner
interest in the same partnership does not result in a deemed sale or exchange of
the converted interests and therefore is not taken into account in determining
whether a constructive termination has occurred. Assuming this ruling is not
revoked or modified, constructive termination of a partnership or a drilling
program is unlikely to occur by reason of the conversion of the interests held
by general partners to limited partner interests.
If a constructive termination of a partnership or a drilling program
occurred, the partnership or the drilling program would be treated as
transferring all of its assets and liabilities to a new partnership in exchange
for an interest in the new partnership and, immediately thereafter, the
partnership or the drilling program would be treated as distributing its
interest in the new partnership to the partners or the participants in
liquidation of the partnership or the drilling program. Such a constructive
termination could have adverse federal income tax consequences, such as the
bunching of taxable income within one taxable period with respect to any
investor partner whose taxable year differs from the partnership's, the
recognition of taxable income by any investor partner who is deemed to receive a
constructive distribution of cash in excess of his basis in interests or his "at
risk" amount at the time of the constructive termination, or the loss of
elections made by the partnership. For additional discussion of the tax
consequences of the conversion, see "-- Special Features of Oil and Gas Taxation
- -- Passive Activity Loss Limitations."
SPECIAL FEATURES OF OIL AND GAS TAXATION
Following is a summary of some of the principal features of United
States federal income taxation of oil and gas operations which may apply to the
partnerships and the drilling programs.
Lease Acquisition Costs. The cost of acquiring oil and gas leasehold or
similar property interests is a capital expenditure which must be recovered
through depletion deductions if the lease is productive. See "-- Special
Features of Oil and Gas Taxation -- Depletion" below. If a lease is proved
worthless and abandoned, the cost of
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acquisition less any depletion claimed may be deducted as an ordinary loss in
the year the lease becomes worthless. See "-- Special Features of Oil and Gas
Taxation -- Depreciation" below.
Geophysical Costs. The cost of geophysical exploration must be
capitalized as a lease acquisition cost if a property is (or may be) acquired or
retained on the basis of data from such exploration. Otherwise, such costs
generally may be deducted as ordinary expenses.
Operating and Administrative Costs. Amounts paid for operating a
producing well are deductible as ordinary business expenses, as are
administrative costs to the extent they constitute ordinary and necessary
business expenses which are reasonable in amount.
Intangible Drilling Costs. Owners of working interests in oil and gas
properties may elect to deduct intangible drilling costs they incur, such as
expenditures for drilling, labor, wages, hauling, fuel, supplies, and other
costs incident to and necessary for the drilling and preparation of wells for
production. The partnerships and the drilling programs will elect to deduct all
intangible drilling costs. Assuming proper elections, each investor partner will
be entitled to deduct his distributive share of the intangible drilling costs
incurred by or allocable to a partnership, subject to the basis, at risk and
passive activity loss limitations discussed below. See "-- Special Features of
Oil and Gas Taxation -- Basis and At Risk Limitations" and "-- Special Features
of Oil and Gas Taxation -- Passive Activity Loss Limitations." Any intangible
drilling costs allocable to a partnership which are incurred prior to the
formation of the partnership are not deductible by the partners even if paid by
the partnership. Such costs must be capitalized as lease acquisition costs. See
"-- Special Features of Oil and Gas Taxation -- Lease Acquisition Costs."
Some capital contributions to a partnership may be expended through the
related drilling program in one year as required under drilling contracts for
services to be performed in the following year. A partnership may deduct such
expenses in the year incurred only if "economic performance" with respect to
such partnership occurs in such year or, subject to limitations, within 90 days
after the close of such year, and all other requirements for deductions by
accrual basis taxpayers are met. In the case of the drilling of an oil and gas
well by an entity such as a partnership, "economic performance" is generally
deemed to occur when the well is spudded (i.e., boring is commenced). Even if
all of these requirements are met, general and limited partners will be entitled
to deduct their share of any such prepayments only to the extent of the "cash
basis" of their interests, determined without regard to any liability of the
partnership and any amount borrowed by an investor partner with respect to the
partnership. If any of these requirements are not satisfied in the year the
expense is incurred, any deductions attributable to such expense would be
deferred to the subsequent year in which the contract to which such expense
relates is performed and subject to tax law in effect at such time. The
deductibility of any intangible drilling costs by a partnership in the year
incurred is an inherently factual determination predicated largely on future
events. Accordingly, counsel to the managing partner is unable to express any
opinion as to the deductibility in a given year of any intangible drilling costs
paid or incurred in a year prior to the performance of the drilling activities
to which such costs relate. If general and limited partners are admitted to a
partnership late in a calendar year and the partnership expends a substantial
portion of its capital or contracts for required prepayments in such year which
do not meet the requirements discussed above, a significant portion of any
material tax benefits associated with an investment in that partnership that
would otherwise be realized in the year of admission would be deferred to a
subsequent year or years and subject to the tax law in effect at such time.
Subject to the limitations discussed above, an investor partner who
qualifies as an "independent producer" (see -- Special Features of Oil and Gas
Taxation -- Depletion) will be entitled to deduct his full share of domestic
intangible drilling costs for federal income tax purposes. An investor partner
who does not qualify as an "independent producer" may currently deduct 70% of
the intangible drilling costs and may amortize the remaining 30% of such costs
over a period of 60 months, except that all costs of dry holes may be deducted
in the year the drilling is completed.
Previously deducted intangible drilling costs will be recaptured as
ordinary income upon the disposition by a partnership of property to which such
deductions relate (to the extent of the gain recognized) or upon the disposition
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by an investor partner of interests. See "-- Special Features of Oil and Gas
Taxation -- Sale of Gas Property" and "-- Special Features of Oil and Gas
Taxation -- Sale of interests."
Depreciation. The cost of equipment such as casing, tubing, tanks,
pumping units, and other similar property may not be deducted currently. Such
costs must be capitalized and recovered through depreciation. The depreciation
deduction for most equipment used in domestic oil and gas exploration and
production is calculated using an accelerated recovery method and a seven-year
recovery period. Each investor partner will be entitled to his distributive
share of a partnership's depreciation deductions, subject to the general
restrictions discussed in this prospectus.
Depletion. Except as discussed below, an investor partner may deduct
for percentage depletion with respect to each oil and gas property of a
partnership. General and limited partners must compute their own depletion
allowance and maintain records of the adjusted basis of property for depletion
and other purposes. While a partnership will furnish its general and limited
partners with information relating to this computation, these requirements may
impose an administrative burden on an investor partner.
Percentage depletion is calculated by the owner of an economic interest
in an oil or gas property, or a partner in a partnership (such as the
partnerships and the drilling programs) which holds such an economic interest as
an amount equal to 15% (and in the case of marginal production an additional 1%,
subject to a maximum increase of 10%, for each whole dollar by which $20 exceeds
the average domestic wellhead price for crude oil for the immediately preceding
fiscal year) of his gross income from the depletable property for the taxable
year. The percentage depletion deduction in respect of any property is limited,
however, to 100% of the taxable income of the owner, or partner, from the
property for each taxable year, computed without the depletion allowance. See
"-- General Tax Provisions -- Alternative Minimum Tax."
Percentage depletion is generally available only with respect to
domestic oil and gas production of certain "independent producers," which, in
general, are persons not directly or indirectly involved in the retail sale of
oil, natural gas, or derivative products or the operation of a major refinery.
An independent producer may deduct percentage depletion only to the
extent his average daily production of domestic crude oil, or the natural gas
equivalent, does not exceed 1,000 barrels. This depletable amount may be
allocated between crude oil and natural gas production, with 6,000 cubic feet of
domestic natural gas production regarded as equivalent to one barrel of crude
oil. The 1,000 barrel limitation must be allocated among the independent
producer and controlled or related persons and family members in proportion to
the respective production by such persons during the period in question.
In addition to the foregoing limitation, the percentage depletion
deduction otherwise available is limited to 65% of the taxpayer's total taxable
income for the year. Any percentage depletion deduction disallowed because of
the 65% limitation may be deducted in the following taxable year if the
percentage depletion deduction for such year plus the deduction carryover does
not exceed 65% of the taxpayer's total taxable income for that year. The
carryover period resulting from the 65% net income limitation is indefinite.
All or a portion of any gain recognized on the disposition of a
depletable property or of interests may be taxed as ordinary income to the
extent of recapture of depletion deductions, except for percentage depletion
deductions in excess of the basis of the property. See "-- Special Features of
Oil and Gas Taxation -- Sale of Property" and "-- Special Features of Oil and
Gas Taxation -- Sale of interests."
Because depletion will be computed separately by each investor partner
and not at the partnership level, no assurance can be given, and counsel to the
managing partner is unable to express any opinion, as to the availability or
extent of percentage depletion deductions to the general and limited partners.
Each prospective investor partner should consult his personal tax advisor to
determine whether percentage depletion would be available to him.
Passive Activity Loss Limitations. Generally, a taxpayer can deduct
losses from "passive activities" only against income from passive activities and
can utilize passive activity tax credits only to offset the tax attributable to
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passive activity income. The taxpayer cannot use passive activity losses to
offset personal earnings, active business income, or investment or portfolio
income, such as interest, dividends, royalties, or gains from the sale of assets
that generate investment or portfolio income, and cannot reduce his tax
liability attributable to those items with passive activity credits.
A passive activity is generally defined as any activity that involves
the conduct of a trade or business in which the taxpayer does not materially
participate. Ownership of limited partner interests will be a passive activity
and a limited partner will be subject to the passive activity loss limitations
with respect to his share of partnership losses and deductions. Consequently, a
limited partner's share of partnership losses and deductions may be deducted
only to the extent of his share of partnership income and any income from other
passive activities. Passive activity losses that may not be utilized because of
the passive activity loss limitations may be carried forward to offset passive
activity income in subsequent years.
Interest income, including interest from any production payments
treated as loans for federal income tax purposes and interest from the
investment of a partnership's working capital or other funds, and royalty income
are treated as portfolio income under the passive activity rules and are not
considered to be income from a passive activity. The Treasury Department also
has the authority to prescribe regulations "requiring net income or gain from a
limited partnership or other passive activity to be treated as not from a
passive activity." No such regulations have been issued to date, and the
Treasury Department has indicated that any subsequent regulations on this
subject would be prospective only. No assurance can be given, however, that
subsequent regulations will not retroactively characterize various items of
partnership income as non-passive.
When a limited partnership disposes of an activity, the limited
partners can deduct their suspended passive activity losses attributable to that
activity. Although unclear, each oil or gas property may constitute a separate
activity for purposes of the passive activity rules. Assuming that each oil or
gas property is a separate activity, whenever a partnership sells an oil or gas
property to an unrelated party or abandons it, each limited partner in that
partnership will then be able to deduct any suspended passive activity losses
attributable to that property. If a partnership disposes of only part of its
interest in a property, however, limited partners will be able to offset only
their suspended passive activity losses attributable to that property against
the gain on the disposition. Any remaining suspended passive activity losses
will remain suspended. Notwithstanding whether an oil and gas property is a
separate activity, when a limited partner sells all his interests, and has no
further interest in the partnership, he will be able to deduct all his suspended
passive activity losses attributable to that partnership.
A taxpayer's interest in an oil or gas well drilled or operated under a
working interest does not constitute a passive activity so long as the taxpayer
owns the working interest directly or through an entity that does not limit the
taxpayer's liability with respect to such drilling or operation. In general, an
entity will be considered to limit the liability of the taxpayer with respect to
the drilling or operation of a well only if, under applicable state law, the
taxpayer's potential liability is limited to a determinable fixed amount.
Indemnification agreements, insurance, stop loss arrangements, or other similar
arrangements are not taken into account in determining whether a taxpayer holds
a working interest through an entity that limits the taxpayer's liability.
Counsel to the managing partner is of the opinion that the passive activity loss
limitations will not apply to general partners in a partnership, prior to any
conversion of their general partner interests to limited partner interests, to
the extent that the partnership drills or operates wells under working
interests. Consequently, each general partner should be entitled to deduct
currently his share of intangible drilling costs and other deductible expenses
allocable to the drilling or operation of wells pursuant to working interests
without regard to the passive activity loss limitations, but subject to the
basis and at risk limitations discussed below. A general partner's share of
partnership income will be non-passive income, however, that may not be offset
by losses from any passive activities. As discussed below, this rule continues
to apply to income attributable to a general partner's interests that have been
converted. The exception for working interests would not be applicable to any
operations of a partnership other than the drilling and operation of wells
pursuant to working interests. Therefore, if a partnership acquires an interest
or participates in other activities, such activities will be treated as passive
activities to the general partners of that partnership and any losses derived by
those general partners with respect to such activities will be passive activity
losses allowable only to the extent discussed above.
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It should be noted that if a general partner is an S corporation, a
limited partnership, a limited liability company, or a trust, the working
interest exception will not apply to the shareholders, limited partners, or
beneficiaries thereof because that form of ownership limits the liability of the
ultimate owners.
As discussed under "Terms of the Offering -- Conversion of General
Partner Interests," the general partner interests in a partnership may be
converted to limited partner interests following the completion of the
partnership's drilling activities. So long as such conversion does not occur
until that time, the interests of the general partners will not be treated as a
passive activity during the drilling period. If, however, a general partner
claims any loss that is treated as an active loss under the working interest
exception, any net income in succeeding taxable years attributable to the
working interest, and any other properties the value of which is enhanced by
drilling, logging, seismic testing, or other activities any part of the costs of
which were borne by the taxpayer as a result of owning such working interest,
will be treated as active income. Thus, if a partnership incurs net losses
during its initial taxable years, any subsequent net income from the partnership
will generally be treated as active income to an investor partner who acquires
general partner interests even after those interests have been converted to
limited partner interests.
If the general partners of a partnership deduct losses under the
working interest exception and their interests are then converted to limited
partner interests during a taxable year, deductions with respect to net loss
wells that are incurred in the year of conversion but after the date of the
conversion are considered passive activity deductions, even if the converted
partners have net income for the taxable year. If the general partner interests
in a partnership are converted to limited partner interests during a taxable
year, this rule may increase both the active income and the passive loss
allocable for such year to the general and limited partners holding those
interests. If the conversion occurs at the beginning of a taxable year, any net
losses of the converted partners for such year will be passive.
The passive activity rules do not apply to corporations, other than S
corporations, personal service corporations, and closely held C corporations. A
closely held C corporation is a corporation in which not more than five
individuals own, directly or indirectly, more than 50% of the value of the
outstanding stock during the last half of the year. An additional exception from
the passive activity rules applies to closely held C corporations that are not
personal service corporations. Such closely held C corporations may deduct
passive activity losses against all of their income except portfolio income.
A special provision of the passive activity rules applies to publicly
traded partnerships. If this special provision were to apply to a partnership,
additional limitations would apply, the most significant of which is that a
limited partner could only deduct his share of partnership losses and deductions
against his share of passive activity income from the partnership. The
definition of "publicly traded partnership" for purposes of this special
provision is the same as the definition of "publicly traded partnership" in
section 7704 of the Internal Revenue Code, except that this special provision
does not include the 90% gross income exception. See "Tax Aspects -- Partnership
Taxation -- Partnership Classification." Based on representations of the
managing partner concerning the anticipated lack of public trading or public
markets for the interests, counsel to the managing partner is of the opinion
that the partnership will not be treated as "publicly traded partnership" for
purposes of the application of the passive activity loss limitations.
Limitations on Interest Deductions. Generally, a taxpayer may deduct
"investment interest" only to the extent of his "net investment income." The
taxpayer may carry forward any unused investment interest to later years when he
has additional net investment income. Investment interest is interest paid on
debt incurred or continued to acquire or carry property held for investment. Net
investment income includes gross income and gains from property held for
investment reduced by any expenses directly connected with the production of
such income and gains. To the extent that interest is attributable to a passive
activity, it is treated as a passive activity deduction and is subject to
limitation under the passive activity rules and not under the investment
interest limitation rules.
Consequently, if a general partner borrows money to purchase interests,
the investment interest limitation may apply to the interest on the debt. In
addition, a general partner's share of partnership income and losses will be
considered investment income and losses for purposes of the investment interest
limitation, and his share of partnership losses will therefore reduce his net
investment income and may affect the deductibility of his other investment
interest, whether or not he borrows to purchase interests.
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Interest expense on debt used by a taxpayer to purchase or carry an
interest in a passive activity will be taken into account in computing the
taxpayer's income or loss from the passive activity. There are detailed tracing
and allocation rules with respect to the allocation of interest expense to
specific expenditures. As a result, the deductibility of interest expense by a
limited partner will depend upon such limited partner's personal tax situation.
Potential investors who contemplate using borrowed funds to purchase limited
partner interests are urged to consult with their tax advisors with respect to
the application and interaction of the investment interest and passive activity
limitations.
It is unclear at present whether, after any conversion of the general
partner interests in a partnership to limited partner interests, interest on
debt incurred by a general partner to purchase his interests will be treated as
investment interest or will be taken into account in computing such partner's
income or loss as a limited partner.
Interest on indebtedness incurred or continued to purchase or carry
tax-exempt securities is not deductible. Investors who currently own or
anticipate acquiring tax-exempt securities and contemplate purchasing interests
with borrowed funds are urged to consult their tax advisors.
Because the deductibility of any interest expense by an investor
partner will depend on such investor partner's personal tax situation, counsel
to the managing partner is unable to express any opinion regarding the federal
income tax treatment of interest expense on indebtedness incurred by an investor
partner to acquire his interests.
For Profit Limitation. In addition to the passive activity limitations
discussed above, an individual who engages in an activity without the intent to
make an economic profit therefrom aside from federal income tax benefits may not
take deductions attributable to such activity in excess of the gross income he
derives from the activity, except for deductions allowable without regard to
profit motive. Thus, in any taxable year in which the deductions of a
partnership exceed its gross income, any investor partner who invested in the
partnership without the requisite economic profit motive may be unable to deduct
substantially all of his distributive share of such excess.
Basis and At Risk Limitations. A partner may not deduct in any year any
amount attributable to his share of partnership losses, if any, which is in
excess of his adjusted tax basis in his interest in the partnership at the end
of the partnership tax year. An investor partner's initial adjusted tax basis in
his interest in a partnership will equal his cash contributions to the
partnership. It will be increased by any additional cash contributions when
made, by his distributive share of partnership income and gain and by his share
of certain borrowings of the partnership. It will be decreased, but not below
zero, by distributions from the partnership, his distributive share of
partnership losses, depletion deductions on his share of partnership oil and gas
income and any decrease in his share of borrowings of the partnership. Decreases
in an investor partner's share of liabilities that have given rise to a basis
increase will be treated as distributions of cash and, thus, will reduce basis.
In addition to the limitation of losses to an investor partner's
adjusted tax basis, losses allocable to such investor partner in excess of
allocable income during a taxable year may be deducted only to the extent of the
amount with respect to which such investor partner is "at risk" at the close of
the taxable year. An investor partner will be at risk as to the amount of money
contributed, assuming such investor partner uses his personal funds to make such
contribution or borrows the funds on a recourse basis from a lender unrelated to
the partnership, and amounts borrowed for use in the partnership for which the
investor partner is personally liable. The at risk amount will be increased by
such investor partner's share of partnership income and gains and the amount by
which such investor partner's percentage depletion deductions with respect to
partnership property exceed such investor partner's share of the basis of such
property. An investor partner will not be at risk with respect to amounts
protected against loss through nonrecourse financings, guarantees, stop loss
agreements, or "other similar arrangements" (which would include the managing
partner's indemnification obligation to general partners for liabilities in
excess of their capital contributions) or with respect to amounts borrowed from
other parties having an interest in the partnership, family members or other
related parties. The at risk amount is reduced by the amount of the allowable
losses for the taxable year, the amount of distributions made to the investor
partner and such investor partner's depletion deductions, and the reduced amount
determines the extent to which losses sustained in future years will be
deductible. Any loss disallowed as a result of the application of the at risk
provisions may be deducted in future years to the extent the
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taxpayer increases his amount at risk. Losses deducted in a year are subject to
recapture in a later year at ordinary income rates in the event, and to the
extent, a taxpayer's adjusted amount at risk falls below zero.
The at risk limitation applies on an activity-by-activity basis, and in
the case of oil and gas properties, each property is treated as a separate
activity. Thus, an investor's interest in each oil or gas property is treated
separately so that a loss from any one property is limited to the at risk amount
for that property and not the at risk amount for all the investor's oil and gas
properties. It is uncertain how this rule is implemented in the case of multiple
oil and gas properties owned by a single partnership. However, for taxable years
ending on or before the date on which further guidance is published, the IRS
will permit aggregation of properties owned by a partnership in computing a
partner's at risk limitation with respect to such partnership. If an investor
partner must compute his at risk amount separately with respect to each property
owned by the partnership, he may not be allowed to utilize his share of losses
or deductions attributable to a particular property even though he has a
positive at risk amount with respect to the partnership as a whole.
Sale of Property. When a partnership sells property, it will recognize
gain to the extent that the amount realized on the sale exceeds its basis in the
property and will recognize loss to the extent that its basis exceeds the amount
realized. In the case of a sale of an oil or gas property, each investor partner
will compute his gain or loss individually based on his share of the amount
realized, as allocated to him under the partnership agreement and the drilling
program agreement, and his share of the basis in such property. The amount
realized will include the amount of money received and the fair market value of
any other property received. If the purchaser assumes a liability in connection
with the sale or takes the property subject to a liability, the amount realized
will include the amount of such liability.
If gain is recognized on such sale, the portion of the gain that is
treated as recapture of intangible drilling cost, depletion, or depreciation
deductions will be treated as ordinary income and the remainder generally will
constitute "Section 1231 gain." If loss is recognized on such sale, such loss
generally will constitute "Section 1231 loss."
Each investor partner will be required to report his share of the
portion of the gain that constitutes recapture as ordinary income and must also
take into account his share of the Section 1231 gains and losses along with his
Section 1231 gains and losses from other sources. The characterization of the
investor partner's share of the Section 1231 gains and Section 1231 losses
attributable to partnership properties as either ordinary or capital will depend
on the total amount of the investor partner's Section 1231 gains and the total
amount of his Section 1231 losses from all sources for the year. Generally, if
the total amount of the gains exceeds the total amount of the losses, all such
gains and losses will be treated as capital gains and losses, and if the total
amount of the losses exceeds the total amount of the gains, all such gains and
losses will be treated as ordinary income and losses. An investor partner's net
Section 1231 gains, however, will be treated as ordinary income to the extent of
the investor partner's net Section 1231 losses during the immediately preceding
five years, reduced by the Section 1231 losses previously recaptured under this
rule.
Termination of a Partnership. When a partnership is terminated, each
investor partner in that partnership will be taxable, in the taxable year in
which the termination occurs, on his share of partnership income, gain, loss,
and deduction arising prior to the date of termination. General and limited
partners must also take into account their shares of gains or losses resulting
from the sale or other disposition of partnership assets in liquidation of the
partnership.
Upon the termination of a partnership, each investor partner in the
partnership will be required to recognize gain to the extent that the amount of
money distributed to him exceeds the basis of his interests or his amount at
risk with respect to the partnership. See "Tax Aspects -- Special Features of
Oil & Gas Taxation -- Basis and At Risk Limitations." An investor partner will
recognize no loss unless he receives only money, unrealized receivables, and
inventory. In such a case, the investor partner could recognize loss to the
extent that the basis of his interests exceeds the aggregate of the money and
the partnership basis of the property received. If, however, an investor partner
receives more or less than his share of ordinary income items, including
potential recapture of intangible drilling
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cost, depletion, and depreciation deductions, the investor partner will be
required to recognize ordinary income or loss to that extent.
An investor partner's basis in any distributed property will be equal
to the basis of his interests, reduced by any money received. The investor
partner's basis will first be allocated to ordinary income assets in an amount
equal to the partnership basis in such assets, which generally will be zero. Any
remaining basis will be allocated, in general, to other properties to the extent
of the partnership's basis in those properties subject to reallocation among
properties designed to reduce basis - value disparities to the extent possible.
Thus, basis increases are allocated to properties with unrealized appreciation
and basis decreases are allocated to properties with unrealized depreciation.
Any basis adjustment remaining after the partnership's basis has been fully
carried over and reallocated is first allocated among those properties with
unrealized appreciation to the full extent of each property's unrealized
appreciation. To the extent that the increase is not fully allocated at this
point, it is allocated in proportion to the properties' respective fair market
values.
Sale of Interests. When an investor partner sells an interest,
including by exercising the right of presentment, he will recognize gain or loss
measured by the difference between the amount realized on the sale and his basis
in the interest sold. The investor partner's amount realized will be the selling
price plus his share of any liabilities that increased his basis in such
interest. For a discussion of the computation of the tax basis in interests, see
"Tax Aspects -- Special Features of Oil & Gas Taxation -- Basis and At Risk
Limitations."
To the extent that the portion of the amount realized attributable to
ordinary income items, including potential recapture of intangible drilling
cost, depletion, and depreciation deductions) exceeds the portion of the basis
allocable to such items, which generally will be zero, the gain will be ordinary
income. Therefore, a substantial portion of any gain realized upon the sale of
interests may constitute ordinary income. So long as the investor partner holds
his interests as a capital asset, generally, an asset held as an investment, the
remainder of the gain will be capital gain and any loss will be capital loss.
The investor partner will be required to recognize the full amount of the
ordinary income portion even if it exceeds the overall gain on the sale (in
which event the investor partner will also recognize capital loss to the extent
the ordinary income exceeds the overall gain) or there is an overall loss on the
sale (in which event the investor partner will recognize an offsetting capital
loss equal to the ordinary income portion and an additional capital loss equal
to the overall loss on the sale). Gain or loss realized by a general partner
upon the sale of interests will generally constitute active income or loss,
while gain or loss realized by a limited partner upon such a sale will
constitute passive income or loss, which passive loss may be used to offset
active income only upon a complete disposition of interests, except in
circumstances where a limited partner has received his interest in a conversion.
See "Tax Aspects -- Special Features of Oil & Gas Taxation -- Passive Activity
Loss Limitations."
Net capital gains of individual taxpayers currently are taxed at a
minimum statutory rate (generally 20% for capital assets held for more than 12
months) which is less than the maximum statutory rate applicable to other income
(39.6%). Net capital gains means the excess of net long-term capital gain over
net short-term capital loss.
Generally, the sale of an interest in a partnership has no effect on
the partnership's basis in its assets. If, however, the partnership has made an
election under Section 754 of the Internal Revenue Code, the partnership's basis
in its assets is adjusted for the benefit of the purchase to reflect the gain or
loss realized by a partner upon the sale of an interest in the partnership. As a
result of the tax accounting complexities inherent in, and the substantial
expense attendant to, the election to adjust the tax basis of partnership
property upon sales of interests, the managing partner does not currently intend
to make this election on behalf of either partnership. Under the partnership
agreement, such election may be made only with the consent of the managing
partner. The absence of any such election and of the power to compel the making
of such an election may reduce the value of interests to a potential transferee
and may be an additional impediment to the transferability of interests.
An investor partner who sells interests must notify that partnership of
the transaction and must attach a statement to his federal income tax return
reciting certain facts regarding the sale. Such notice must be given in writing
within 30 days of the sale, or, if earlier, by January 15 of the year following
the year in which the sale occurs, and must include the names and addresses of
the buyer and seller, the taxpayer identification numbers of the buyer and
seller, if known, and the date of the sale. An investor partner who fails to
furnish the relevant information to the
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partnership may be penalized $50 for each such failure, unless it is shown that
such failure was due to reasonable cause and not willful neglect. In addition,
the partnership will be required to notify the IRS of any sale of an interest of
which it has notice or knowledge and to report the names, addresses, and
taxpayer identification numbers of the buyer and seller, along with other
required information. The partnership is also required to provide copies of the
information it provides to the IRS to the buyer and seller.
Section 1060 of the Internal Revenue Code may also require both the
buyer and seller of an interest to file statements with their federal income tax
returns stating their agreement, if any, concerning the allocation of the
purchase price among assets.
Farmouts and Backin Interests. One of the various ways in which a
partnership, through the drilling program, may acquire an oil and gas lease is
through a farmout, discussed above under "Proposed Activities -- Farmouts." Some
farmouts may be characterized for tax purposes as partnerships entered into by
the related drilling program and the other party to the farmout. The manner in
which the parties to these farmouts agree to allocate income, gain, loss,
deduction, and credit, or any item of income, gain, loss, deduction and for
credit, may be disallowed under Section 704 of the Internal Revenue Code. See
"-- Partnership Taxation -- Allocations." If the farmout creates a co-ownership
arrangement, the drilling program may be required to capitalize a portion of the
intangible drilling costs paid in excess of its fractional share of the working
interest acquired under the agreement. If the farmout creates an arrangement
that is classified as an association taxable as a corporation for federal income
tax purposes, the tax benefits of investing in that partnership would be
adversely affected, or eliminated See -- "Partnership Taxation -- Partnership
Classification." One type of farmout in which a drilling program might be
involved is a transaction in which, in exchange for the drilling of a well on a
particular drill site, the drilling party becomes entitled to an assignment of
100% of the leasehold interest in the drill site acreage, until such time as his
or its drilling, completion and production costs are recovered out of production
therefrom, with a lesser percentage thereafter, and a lesser fractional interest
in the portion of the tract exclusive of the drill site acreage. The IRS has
ruled, in Revenue Ruling 77-176, 1977-1 C.B. 77, that any transfer of rights in
property other than the drill site acreage in this type of transaction would be
deemed a sale of such other property by the party transferring the property on
which gain or loss is realized. The IRS further ruled that, while the party
receiving the acreage and incurring the cost of drilling the well on the drill
site may elect to deduct such costs as intangible drilling and development
costs, such party would realize ordinary income equal to the value of the
acreage earned exclusive of the drill site acreage.
The managing partner will attempt to structure any farmout or similar
transaction in a way which either eliminates or minimizes to the fullest extent
possible the tax consequences set forth in this ruling and the other adverse tax
consequences described above. Nonetheless, the ruling may have adverse tax
implications for a drilling program and the related partnership if and when a
drilling program enters into such farmouts, since such drilling program may
recognize gain or loss upon the transfer or receipt of an interest in the
property.
GENERAL TAX PROVISIONS
Following is a brief summary of some additional federal income tax laws
which may impact upon an investor partner.
OTHER TAX CONSEQUENCES
Alternative Minimum Tax. The individual alternative minimum tax is
imposed at graduated rates of 26% and 28% on "alternative minimum taxable
income" in excess of exemption amounts. The tax thus computed is reduced by the
taxpayer's regular tax liability.
Alternative minimum taxable income is computed by increasing regular
taxable income by tax preference items and recomputing certain items. For an
individual taxpayer, adjustments include such items as the difference between
accelerated depreciation deductions and depreciation deductions under the
alternative system of Section 168(g) of the Internal Revenue Code using the 150
percent declining balance method with respect to tangible personal property and
the straight-line method with respect to real property.
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The passive activity limitations also apply for purposes of computing
alternative minimum taxable income, although tax preference items taken into
account for purposes of the passive activity rules are not taken into account in
computing alternative minimum taxable income.
Corporations are subject to an alternative minimum tax of 20% of
alternative minimum taxable income to the extent that such amount exceeds the
greater of (a) the corporation's federal income tax liability or (b) certain
exemption amounts. Corporate items of tax preference include items similar to
those described above for individuals, and a number of additional items.
Because an investor partner's liability for the alternative minimum tax
is computed by taking into account his regular income tax liability, the extent
to which any tax preference items directly or indirectly resulting from an
investment in interests would be subject to the alternative minimum tax will
depend on the facts of his particular situation. For a taxpayer with substantial
tax preference items, the alternative minimum tax could reduce the after-tax
economic benefit of his investment in interests. Each potential investor should
consult his tax advisor concerning the impact of the alternative minimum tax on
his investment in interests.
Tax Shelter Registration. An organizer of a "tax shelter" must register
the tax shelter with the Secretary of the Treasury and obtain an identification
number which must be included on the tax returns of investors in the shelter.
Any person who organizes any "potentially abusive tax shelter" must maintain
lists of investors therein and make such information available to the Secretary
of the Treasury upon request.
In view of the expansive definition of the term "tax shelter" under
temporary regulations, the tax shelter registration provisions could be
interpreted to apply to the partnerships. The managing partner will apply for
and obtain a tax shelter registration number with respect to each partnership.
The registration number of a partnership will be furnished to its general and
limited partners, who must include the number on their tax returns for any year
in which any deduction, loss, credit, other tax benefit or any income
attributable to the partnership is claimed or reported, and must furnish the
number to any transferee of their interests, together with other required
information. The managing partner also must maintain lists of investors in the
partnerships and make such lists available to the IRS on request.
ISSUANCE OF A REGISTRATION NUMBER DOES NOT INDICATE THAT THIS
INVESTMENT OR THE CLAIMED TAX BENEFITS HAVE BEEN REVIEWED, EXAMINED OR APPROVED
BY THE INTERNAL REVENUE SERVICE.
Changes in Federal Income Tax Laws. Significant and fundamental changes
in the nation's federal income tax laws have been made in recent years and
additional changes are likely. Any such change may affect the partnerships and
the general and limited partners. Moreover, judicial decisions, regulations or
administrative pronouncements could unfavorably affect the tax consequences of
an investment in a partnership. See "Tax Aspects -- Other Tax Consequences --
Changes in Federal Income Tax Laws."
Compliance Provisions. Taxpayers are subject to several penalties and
other provisions which encourage compliance with the federal income tax laws,
including an addition to tax of 20% of a "substantial understatement" of federal
income tax. This addition is imposed if an understatement of tax exceeds the
greater of (a) 10% of the tax required to be shown on the return or (b) $5,000
($10,000 for a corporation other than an S corporation or a personal holding
company).
Except in the case of understatements attributable to "tax shelter"
items, an item of understatement will not give rise to the penalty if (a) there
is or was "substantial authority" for the taxpayer's treatment of the item or
(b) all facts relevant to the tax treatment of the item are disclosed on the
return or on a statement attached to the return. In the case of partnerships,
the disclosure is to be made on the return of the partnership. However, an
individual partner may make adequate disclosure with respect to partnership
items if specific conditions are met.
In the case of understatements attributable to "tax shelter" items, the
substantial understatement penalty may be avoided only if the taxpayer
establishes that, in addition to having substantial authority for his position,
he reasonably believed the treatment claimed was more likely than not the proper
treatment of the item. A "tax shelter"
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item is one that arises from a partnership, or other form of investment, a
significant purpose of which is the avoidance or evasion of federal income tax.
An entity should not be considered to have a significant purpose of avoidance or
evasion of federal income tax merely because it avails itself of percentage
depletion allowances, intangible drilling cost deductions, or certain other
deductions. The managing partner does not believe that tax avoidance is a
significant purpose of either partnership and does not anticipate that these
provisions would apply to any understatement attributable to the disallowance of
a partnership item. Investors are cautioned, however, to consult their tax
advisors with respect to the possible application of the substantial
understatement penalty.
Consistency Requirements. General and limited partners must generally
treat partnership items on their federal income tax returns consistently with
the treatment of such items on the partnership information return, unless an
investor partner files a statement with the IRS identifying the inconsistency or
otherwise satisfies the requirements for waiver of the consistency requirement.
Failure to satisfy this requirement will result in an adjustment to conform the
investor partner's treatment of the item with the treatment of the item on the
partnership return. Intentional or negligent disregard of the consistency
requirement may subject an investor partner to substantial penalties.
Nominees. A person who holds a partnership interest as a nominee for
another person must furnish to the partnership the name and address of the
beneficial owner, along with any other information prescribed by form or
regulations. A notice issued by the IRS requires the nominee to furnish to the
partnership the nominee's name, address, and taxpayer identification number, the
taxpayer identification number of the beneficial owner and information
concerning the partnership interests held, acquired, and disposed of by the
nominee on behalf of others during the partnership taxable year. The nominee
also must provide certain information to the beneficial owner of the interest,
and the partnership must furnish certain information to the nominee. Regulations
to be issued may impose additional requirements. Any prospective investor who is
acting as a nominee for another person should consult his tax advisor regarding
these requirements.
Social Security Benefits; Self-Employment Tax. A general partner's
share of any income or loss attributable to interests will constitute "net
earnings from self-employment" for both social security and self-employment tax
purposes, while a limited partner's share of such items will not constitute net
earnings from self-employment. Thus, no quarters of coverage or increased
benefits under the Social Security Act will be earned by limited partners. If a
general partner is receiving Social Security benefits, his taxable income
attributable to his investment in interests may be taken into account in
determining any reduction in benefits because of "excess earnings."
Investment by Tax-Exempt Entities. Net income derived from the conduct
of a trade or business regularly carried on by many tax-exempt entities,
including charitable or other exempt organizations, pension, profit-sharing or
stock bonus plans, Keogh plans, IRAs, and other employee benefit plans, may
constitute unrelated business taxable income on which federal income tax is
imposed. Unrelated business taxable income in excess of $1,000 of a tax-exempt
entity which is a corporation is generally taxed at marginal corporate rates.
Where the tax-exempt entity is a trust, unrelated business taxable income in
excess of $1,000 is taxed at marginal trust rates. Ownership of a working or
operating interest in oil or gas properties has been held to constitute income
derived from the conduct of a trade or business, even where an unrelated third
party is hired to operate the property and ownership is in the form of a
partnership. To the extent a partnership borrows funds to acquire or improve a
property or a tax-exempt entity borrows funds to acquire interests, a portion of
the income from such "debt financed property" may be unrelated business taxable
income even if otherwise excludable. For these reasons, it is expected that
substantially all the income of the partnerships will constitute unrelated
business taxable income. An otherwise tax-exempt investor partner may be
required to file a tax return even if such investor does not realize net taxable
income from a partnership exceeding $1,000.
Fiduciaries of pension, profit sharing or stock bonus plans, Keogh
plans, IRAs, other qualified employee benefit plans, and other plans or
arrangements subject to ERISA, or to Section 4975 of the Internal Revenue Code,
must determine whether an investment in interests will satisfy required
standards, including, among other things:
o the exclusive purpose rule of Section 404(a)(1)(A) of ERISA,
o the prudence requirements of Section 404(a)(1)(B) of ERISA,
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o the diversification requirements of Section 404(a)(1)(C) of
ERISA, and
o the requirement of Section 404(a)(1)(D) of ERISA that the
investment be in accordance with the governing instrument of
the plan or arrangement.
A fiduciary of an employee benefit plan or other arrangement is
prohibited from engaging in certain transactions involving "plan assets" with
parties which are "parties in interest" under ERISA or "disqualified persons"
under the Internal Revenue Code. The United States Department of Labor has
issued final regulations defining "plan assets" for these purposes. Under
certain circumstances, the final regulations treat a portion of the underlying
assets of an entity in which such a plan or arrangement invests as assets of the
plan or arrangement. These regulations could apply to a partnership, unless the
partnership satisfies one of the exceptions set forth in such regulations. It is
anticipated that each partnership will qualify for the "publicly offered
security" exception and that the underlying assets of a partnership should not
be considered "plan assets" for purposes of these regulations. Such issue
involves questions of fact, however, and counsel to the managing partner is not
rendering any opinion as to whether interests will be considered "publicly
offered securities" for purposes of ERISA. Each prospective investor which is or
may be subject to ERISA or to Section 4975 of the Internal Revenue Code should
consult with its advisors concerning the effect of its ownership of interests
under these rules.
State Law Tax Aspects. A partnership, through the related drilling
program, will operate in states and localities which impose taxes on the
partnership's assets or income or on each investor partner based upon his share
of any income derived from partnership activities in such jurisdictions.
Depending upon the location of the partnership's properties and applicable state
and local laws, deductions or credits available to an investor partner for
federal income tax purposes may not be available for state or local income tax
purposes.
It is anticipated that a significant portion of the partnerships'
activities will be in Texas, which imposes a franchise tax on corporations and
limited liability companies "doing business" in that state. General partners
which are corporations or limited liability companies not otherwise considered
to be doing business in Texas which invest through a partnership may be deemed
to be doing business in Texas for purposes of this tax.
To the extent a partnership operates in certain jurisdictions, estate
or inheritance taxes may be payable therein upon the death of an investor
partner. Therefore, an investor partner may be subject to income taxes, estate
or inheritance taxes or both in states or localities in which the partnership
does business as well as in his own state and domicile.
ANTICIPATED FEDERAL INCOME TAX DEDUCTIONS
The managing partner expects that approximately 75% to 85% of an
investor partner's capital contribution to a partnership will be deductible or
eligible for deduction for federal tax purposes either in the tax year in which
such capital contribution is made or in the subsequent tax year. Due to the
application of the passive activity loss limitations, the percentages of capital
contributions of limited partners that will be deductible will depend largely
upon each such limited partner's tax situation independent of his investment in
interests, and are thus impossible to estimate. These estimates are based upon
the managing partner's assumptions concerning the offering termination dates for
the partnerships and the managing partner's previous experience concerning the
deductibility of the costs of drilling and completing wells and current federal
income tax law. Further, the estimates are based upon a number of factual
assumptions, including an assumption that contracts calling for the expenditure
of a substantial portion of the capital of each partnership will be entered into
in such year and that such expenditures will meet applicable statutory and
judicial requirements for deductibility in that year. See "Risk Factors -- Tax
Risks -- Current Tax Deductions." ACCORDINGLY, THERE CAN BE NO ASSURANCE THAT
THESE ESTIMATED PERCENTAGES OF CAPITAL CONTRIBUTIONS WILL BE DEDUCTIBLE OR
ELIGIBLE FOR DEDUCTIBILITY IN THE YEAR IN WHICH THE CAPITAL CONTRIBUTION IS
MADE.
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INDIVIDUAL TAX ADVICE SHOULD BE SOUGHT
THE TAX CONSIDERATIONS ATTENDANT TO AN INVESTMENT IN A PARTNERSHIP ARE
COMPLEX AND VARY WITH INDIVIDUAL CIRCUMSTANCES. EACH PROSPECTIVE INVESTOR
PARTNER SHOULD REVIEW SUCH TAX CONSEQUENCES WITH HIS TAX ADVISOR.
COMPETITION, MARKETS AND REGULATION
COMPETITION
There are a large number of companies and individuals engaged in
exploration for oil and gas and development of oil and gas properties.
Accordingly, the partnerships will encounter strong competition from independent
operators and major oil companies in acquiring oil and gas leases suitable for
development by the partnerships and the related drilling programs. Many of the
companies so engaged have financial resources and staffs considerably larger
than those available to the partnerships.
MARKETS FOR SALE OF PRODUCTION
The ability of a partnership to market oil and natural gas found and
produced, if any, will depend on numerous factors beyond the control of the
partnership, the effect of which factors cannot be accurately predicted or
anticipated. Some of these factors include, without limitation the availability
of other domestic and foreign production, the marketing of competitive fuels,
the proximity and capacity of pipelines, fluctuations in supply and demand, the
availability of a ready market, the effect of United States federal and state
regulation of production, refining, transportation and sales and general
national and worldwide economic conditions. At the present time worldwide oil
production capacity and gas production capacity in certain areas of the United
States exceed demand. This has resulted in a substantial decline in the price of
oil and natural gas in the United States. Although future levels of production
by members of OPEC or the degree to which oil prices will be affected by those
levels of production cannot be predicted, it is possible that prices for any oil
and gas produced from a program well will be lower than those currently
available. There is no assurance that a partnership will be able to market any
oil or natural gas produced by it, or, if such oil or natural gas is marketed,
that favorable prices can be obtained by the partnership. See "Risk Factors --
General Risks Relating to Oil and Natural Gas -- Dependence on Future Prices,
Supply and Demand for Oil and Gas."
The United States natural gas market has undergone several significant
changes over the past few years. The majority of federal price ceilings were
removed in 1985 and the remainder were lifted by the Natural Gas Wellhead
Decontrol Act of 1989. Thus for the first time in many years, the United States
natural gas market is operating in a free market environment in which the
contracts between the seller and buyer determine the price of gas.
At the same time, the domestic natural gas industry has also seen a
dramatic change in the manner in which gas is bought, sold, and transported.
Newly developed supplies of natural gas are, in most cases, no longer sold to a
pipeline company. Instead, the pipeline company now serves the role of
transporter primarily, and gas producers are free to sell their product to
marketers, local distribution companies, end users, or a combination thereof.
This process, which began with the issuance of the Federal Energy Regulatory
Commission ("FERC") open access transportation program, often known as Order No.
436, and culminated with the implementation of FERC Order No. 636 - the
restructuring rule, has greatly enhanced a producer's ability to avoid shut-ins
or curtailments because in the new gas environment, a producer now has a
multitude of buyers to choose from.
Recent trends indicate substantial improvement in the price received
for natural gas. Many analysts believe that the industry is finally experiencing
the combined effects of declining deliverability, reduced reserve replacement
and increased demand for natural gas as a fuel of choice. While this trend is
expected to continue, natural gas prices will still probably remain somewhat
seasonal in nature and, for this reason, it is particularly difficult to
estimate
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accurately future prices of gas, and any assumptions concerning future prices
may prove incorrect. See "Competition, Markets and Regulation".
The United States average daily production of oil declined from 9.0
million barrels in 1985 to approximately 6.0 million barrels in 1999. The
reduced production level is in part the result of decreased drilling activity in
the United States. Drilling activity is measured by the United States rig count.
The United States rig count hit an historical high in 1981 of over 4,500 rigs
and was 771 rigs as of the end of 1999. Another factor contributing to the
reduction of United States oil production is the plugging and abandoning of
wells which are uneconomical due to the significant decrease in the price of
oil.
The United States import levels for oil have increased significantly
since 1985. In 1985, imports of foreign oil represented 27% of the United
States' demand. During the year 1999 imports averaged approximately 58% of the
United States' consumption.
In view of the many uncertainties affecting the supply and demand for
oil, gas, and refined petroleum products, the managing partner is unable to
predict future oil and gas prices or the overall effect, if any, that the
decline in demand for and the oversupply of such products will have on a
partnership.
REGULATION OF PRODUCTION
The production of oil and gas found by a drilling program, if any, will
be subject to United States federal and state laws and regulations, and orders
of regulatory bodies under those laws and regulations, governing a wide variety
of matters, including the drilling and spacing of wells on producing acreage,
allowable rates of production, marketing, prevention of waste and pollution, and
protection of the environment. Such laws, regulations, and orders may restrict
the rate of oil and gas production below the rate which would otherwise exist in
the absence of such laws, regulations, and orders, and may restrict the number
of wells which may be drilled on a particular oil and gas lease.
NATURAL GAS PRICES
The Natural Gas Wellhead Decontrol Act of 1989 was enacted on July 26,
1989, and provides that all gas prices are decontrolled at the wellhead
effective January 1, 1993. Accordingly, sales of natural gas by a partnership
generally will not be subject to the maximum lawful price ceilings set by the
Natural Gas Policy Act of 1978, as amended. Thus, market conditions will
determine the prices that a partnership receives from the sale of natural gas
produced from program wells.
OIL AND LIQUID HYDROCARBON PRICE CONTROLS
There are currently no federal price controls on oil production, and
sales of oil, condensate, and natural gas liquids by a partnership can be made
at uncontrolled market prices. However, there can be no assurance that Congress
will not enact controls at any time.
State statutory provisions relating to oil and gas generally require
permits for the drilling of wells and also cover the spacing of wells, the
prevention of waste, the rate of production, the prevention and clean-up of
pollution, and other matters. For example, the Railroad Commission of Texas
determines the amount of gas producers can produce and purchasers can take from
oil and gas leases located within the State of Texas.
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POSSIBLE LEGISLATION
Currently there are many legislative proposals pertaining to regulation
of the oil and gas industry, which proposals may directly or indirectly affect
the activities of a partnership. No prediction can be made as to what additional
energy legislation may be proposed, if any, nor which bills may be enacted nor
when any such bills, if enacted, would become effective.
REGULATION OF THE ENVIRONMENT
The exploration, development, and production of oil and gas is subject
to various federal and state laws and regulations to protect the environment.
Various states and governmental agencies are considering, and some have adopted,
other laws and regulations regarding environmental control which could adversely
affect the business of a partnership. Compliance with such legislation and
regulations, together with any penalties resulting from noncompliance therewith,
will increase the cost of oil and gas development and production. All or a
portion of these costs may ultimately be borne by a partnership.
The preceding discussion of regulation of the oil and gas industry is
necessarily brief, and is not intended to constitute a complete discussion of
the various statutes, rules, regulations, or governmental orders to which the
partnerships' and the drilling programs' operations may be subject.
LIABILITY OF GENERAL AND LIMITED PARTNERS
GENERAL PARTNERS
By law, each general partner in a partnership is liable for all of the
liabilities and recourse obligations of the partnership. Accordingly, a single
general partner legally could be held responsible for the liabilities and
obligations of an entire partnership. Furthermore, under some circumstances,
joint working interest owners may be jointly and severally liable for
obligations arising in connection with the development and operation of the oil
and gas lease in which they jointly own an interest. See "Risk Factors --
Particular Risks Relating to the Interests -- Liability of Joint Working
Interest Owners." Because a partnership will own a working interest in leases in
which the participants in the drilling program, and likely others, own working
interests, the partnership, and therefore the general partners of that
partnership, could be liable for obligations of all such joint working interest
owners.
Under the terms of the partnership agreements, the general partners and
the managing partner of each partnership will agree that, as among themselves,
each general partner and the managing partner will be responsible only to pay
his pro rata share of that partnership's liabilities and obligations, and will
be entitled to contribution from other general partners and the managing partner
of a partnership if he incurs liability in excess of his pro rata share.
Furthermore, the managing partner will indemnify each general partner of the
partnership. The managing partner will undertake to indemnify each general
partner for any and all partnership-related obligations and liabilities
otherwise allocable to or paid by such general partner which are in excess of
such general partner's share of the partnership's undistributed assets. However,
such contribution rights and indemnity do not legally negate a general partner's
liability for a partnership's obligations, and a general partner still could be
subject to liability in excess of the amount of his capital contribution if the
managing partner should become bankrupt or for any other reason are unable to
meet the financial commitments of the indemnity. This liability could result in
the necessity for a general partner to make additional payments to the
partnership. Due to the uncertain nature of any such liability, it is not
possible to determine the amount of any such liability.
The managing partner will conduct the operations of each partnership in
a manner designed to reduce the risk that a general partner could be required to
make such additional payments. See "Insurance."
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LIMITED PARTNERS
Under Delaware law, a limited partner is not liable for the obligations
of a limited partnership unless he is also a general partner or, in addition to
the exercise of his rights and powers as a limited partner, he participates in
the control of the partnership's business, and then only to persons who transact
business with the limited partnership reasonably believing, based upon the
limited partner's conduct, that the limited partner is a general partner.
Delaware law provides that certain acts, including the exercise of the right to
vote on matters specified in the partnership agreement, do not constitute
participation by a limited partner in the control of a limited partnership's
business. Assuming that a limited partner does not take part in the control of a
partnership's business and that he otherwise acts in conformity with the
provisions of the partnership agreement, his liability under Delaware law will
be limited, subject to possible exceptions, generally to the amount of capital
he has contributed to the partnership. Under Delaware law (i) a limited partner
is obligated to a partnership to perform any promise to contribute cash or
property or perform services, even if he is unable to perform because of death,
disability, or other reason, and such obligation may be enforced by a third
party creditor of the partnership and (ii) a limited partner may be liable to
the extent of prohibited distributions (as described below) made to the limited
partner, if he knew, at the time of the distribution, that it was prohibited. A
limited partner's liability for the return of any distribution terminates,
however, after the expiration of three years from the date of the distribution.
Under Delaware law, a limited partner may not receive a distribution from a
partnership to the extent that at the time of and after giving effect to the
distribution, all liabilities of the partnership, other than liabilities to
limited partners on account of their interests, exceed the fair value of the
partnership's assets. Under Delaware law, an assignee who becomes a substituted
limited partner of a partnership is liable for the obligation of his assignor to
make capital contributions, except that the assignee is not obligated for
liabilities unknown to him at the time he became a limited partner and that
could not be ascertained from the partnership agreement.
It is currently anticipated that the partnerships will conduct
substantially all of their business in the states of Texas, Oklahoma, Kansas and
New Mexico, where each partnership will register to do business as a foreign
limited partnership. A partnership may also be deemed to be conducting business
in various states, other than Texas, Oklahoma, Kansas and New Mexico, in which
the partnership acquires and operates properties. The applicability of state
laws to limited partners of a limited partnership such as a partnership in such
a situation and limitations of the liability of limited partners for the
obligations of the limited partnership have not been clearly established in many
jurisdictions. If it were determined that the right or exercise of the right by
the limited partners as a group to remove or replace the managing partner, to
make certain amendments to the partnership agreement, or to take other action
under the partnership agreement, constitute "control" of a partnership's
business for the purposes of the statutes of any relevant jurisdiction, a
limited partner might be held personally liable for a partnership's obligations
under the laws of such jurisdiction. Further, under the laws of certain
jurisdictions, a limited partner might be liable for other amounts, such as the
amount of any undistributed profits to which such limited partner is entitled,
with interest, or interest on the amount of capital contributions rightfully
returned to him. Maintenance of limited liability will require compliance with
legal requirements in such jurisdictions. The partnerships and the drilling
programs will operate in such a manner as its managing partner deems reasonable,
necessary and appropriate to preserve the limited liability of limited partners.
The following table summarizes the key differences in the treatment
afforded limited partners, general partners and the managing partner under
Delaware law.
LIMITED PARTNERS GENERAL PARTNERS MANAGING PARTNER
---------------- ---------------- ----------------
General liability for all of the No Yes Yes
obligations of a partnership
Limited liability for the obligations Yes No Yes
of a partnership to the extent of
capital contributions (subject to indemnification)
Right to indemnification by us for Not Applicable Yes Yes
any amounts due in excess of
capital contributions to the
partnership
Right to participate in the No No Yes
management and operations of the (delegated
partnership to managing partner)
Right to deduct intangible drilling Yes (but limited to deductions Yes (not limited to Yes (not limited to
costs against income from passive deductions against deductions against
activities) income from passive income from passive
activities but subject activities but subject
to "At Risk" and basis to "At Risk" and basis
limitations) limitations)
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SUMMARY OF PARTNERSHIP AGREEMENT AND DRILLING PROGRAM AGREEMENT
The following is a summary of the provisions of the partnership
agreements and the drilling program agreements. This summary is qualified in all
respects by reference to the full text of the Form of Partnership Agreement,
which appears as Exhibit A to this prospectus; and the Form of Drilling Program
Agreement, which appears as Exhibit B to this prospectus. Each prospective
purchaser is urged to review, and be advised with respect to the effect of, the
provisions of the partnership agreement and the drilling program agreement.
TERM
Each partnership will be organized under the Delaware Revised Uniform
Limited Partnership Act. Each drilling program will be a partnership for income
tax purposes only and, for all other purposes, is intended to be an agreement
among Mewbourne Oil Company, as drilling program manager, and the managing
partner and a partnership as joint owners or tenants-in-common of undivided
working interests in the drilling program's oil and gas properties. Each
partnership and the related drilling program will continue until terminated as
provided for in the partnership agreement and the drilling program agreement.
See "-- Dissolution, Liquidation and Termination" below.
RIGHTS AND POWERS OF PARTNERS
General and Limited Partners. Under the terms of the partnership
agreements, general and limited partners will have the following rights and
powers with respect to their respective partnership:
(a) to share all charges, credits, and distributions in
accordance with the partnership agreement and share all charges,
credits, and distributions of the related drilling program through the
partnership as discussed under "Participation in Costs and Revenues",
(b) to inspect at their expense books and records relating to
the activities of the partnership through the drilling program, upon
adequate notice and at all reasonable times, other than geophysical,
geological and other similar data and information and studies, maps,
evaluations, and reports derived therefrom which for a reasonable
period of time may be kept confidential because the managing partner
has agreed to keep such matters confidential or has determined in good
faith that such matters should be kept confidential considering the
interests of the partnership and each of its partners, and upon written
request at their expense to have a copy of a list of names and
addresses of all partners mailed to them,
(c) to have on demand true and full information of all
activities of the partnership, through the drilling program, and a
formal account of affairs whenever circumstances render it just and
reasonable,
(d) to have dissolution and winding up of the partnership by
decree of court as provided under Delaware law,
(e) to reconstitute the partnership with a new managing
partner upon the withdrawal or retirement of the managing partner from
the partnership, directly or as a result of a bankruptcy, dissolution,
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or similar event that would dissolve the partnership, which causes the
dissolution of the partnership upon the election of a majority in
interest of the general and limited partners,
(f) to terminate any contract between the partnership and the
managing partner or any affiliate of the managing partner by a vote or
written consent of a majority in interest of the general and limited
partners, without penalty upon 60 days' written notice,
(g) to approve the sale of all or substantially all of the
assets of the partnership, except upon liquidation of the partnership,
by the affirmative vote of a majority in interest of the general and
limited partners, except in connection with a roll-up transaction which
requires the affirmative vote of at least 66% in interest of the
general and limited partners,
(h) to dissolve the partnership at any time upon the election
of a majority in interest of the general and limited partners,
(i) to permit the assignment by the partnership or the
managing partner of their obligations under the drilling program
agreement, if such permission is required under the drilling program
agreement, by the affirmative vote of a majority in interest of the
general and limited partners,
(j) to agree to the termination or amendment, except for
certain conformatory amendments and amendments necessary to conform to
the Internal Revenue Code or that do not adversely affect the general
and limited partners, of the drilling program agreement or the waiver
of any rights of the partnership under the drilling program agreement
by the affirmative vote of a majority in interest of the general and
limited partners,
(k) to remove the managing partner and substitute a new
managing partner to operate and carry on the business of the
partnership or, to remove the drilling program manager and substitute a
successor to act in such capacity by the affirmative vote of a majority
in interest of the general and limited partners, and
(l) to propose and vote on certain matters affecting the
partnership as provided in the partnership agreement.
Limited Partners. Limited partners of a partnership will take no part
in the control of the business or affairs of the partnership or the related
drilling program and will have no voice in the management or operations of that
partnership or drilling program. This lack of management and control is
necessary to insulate the limited partners from liability in excess of their
investment in the partnership and their share of undistributed profits from the
partnership. See "Risk Factors -- Particular Risks Relating to the Interests --
Liability of Limited Partners" and "Liability of General and Limited Partners --
Limited Partners." Notwithstanding the foregoing, limited partners shall:
o have the rights described in paragraphs (a) through (l) under
the caption "general and limited partners" above, and
o have their liability for operations of the partnership and the
drilling program limited to the amount of their capital
contributions and to their shares of partnership capital and
undistributed net revenues of the partnership, if any;
provided, however, that under Delaware law the limited
partners may under certain circumstances be required to repay
the partnership amounts previously distributed to them by the
partnership if the partnership does not have sufficient other
assets to satisfy the claims of creditors.
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General Partners. The general partners will delegate to the managing
partner the responsibility for the day-to-day operations of the partnerships. In
addition, the general partners will covenant not to exercise the following
rights granted to them under Delaware law:
o the right to withdraw from the partnership,
o the right to act as agent of the partnership or to execute
documents on behalf of the partnership, and
o the right to act other than together with other general
partners constituting a majority in interest of the general
and limited partners to cause the managing partner on behalf
of the partnership to convey partnership property or take any
other action binding on the partnership.
A general partner who violates such covenants is obligated to indemnify the
partnership and the other partners for any loss or liability caused by such
violation. Furthermore, in the event of a dissolution caused by a withdrawing
general partner, upon reconstitution of the partnership, the withdrawing general
partner shall remain subject as a general partner to any liabilities or
obligations of the partnership arising prior to such withdrawal. Upon withdrawal
from the partnership, a general partner is entitled to continue to receive any
distributions to which he is otherwise entitled under the partnership agreement
for the period prior to his withdrawal; however, such general partner shall not
be entitled to receive the fair value of his interest in the partnership as of
the date of such withdrawal based upon his right to share in distributions from
the partnership, and neither the partnership nor the managing partner has any
obligation to repurchase any interest in the partnership from the withdrawing
general partner. The withdrawing general partner will no longer be entitled to
receive any distributions nor shall such general partner have any rights as an
investor partner under the partnership agreement. The sharing ratios will be
recalculated among the general and limited partners without regard to the
withdrawing general partner's capital contribution. See "-- Reconstitution of
the Partnership" below.
RIGHTS AND POWERS OF THE MANAGING PARTNER
The managing partner has full and exclusive power, except as limited by
the partnership agreement and applicable law, to manage, control, administer,
and operate the properties, business, and affairs of a partnership. The managing
partner has the authority to enter into a drilling program agreement on behalf
of a partnership. Under the drilling program agreements, Mewbourne Oil Company
as drilling program manager will have the power and authority to act on behalf
of a partnership with respect to the management, control, and administration of
the business and affairs of the related drilling program and the properties
subject to the drilling program agreement.
Under the partnership agreements, the managing partner is required to
devote only such time and effort to the business of the partnership as may be
necessary to promote adequately the interests of that partnership and the mutual
interests of the partners. The managing partner is permitted to engage in any
other business ventures, including the ownership and management of oil and gas
properties and the organization and management of other drilling programs.
See "Conflicts of Interest."
INDEMNIFICATION OF THE MANAGING PARTNER AND ITS AFFILIATES
The partnership agreements provides that neither the managing partner
nor any of its affiliates shall be liable to a partnership or the general and
limited partners for any loss suffered by the partnership which arises out of
any action or inaction performed or omitted by the managing partner or such
affiliate, if the managing partner in good faith has determined, as of the time
of the conduct or omission, that the course of conduct or omission was in the
best interest of the partnership, the managing partner or such affiliate was
acting on behalf of or performing services for the partnership, and that such
conduct or omission did not constitute negligence or misconduct. The drilling
program manager and its affiliates, under the drilling program agreement, have
similar liability.
The partnership agreements also provide that the managing partner and
its affiliates shall be indemnified by a partnership, only from the tangible net
assets of the partnership and not from other assets of the partners, from and
against all losses, judgments, liabilities, expenses, and settlements sustained
by them in connection with acts performed or omitted by the managing partner or
affiliates acting on behalf of or performing services for that partnership or
the related drilling program; provided that, unless otherwise ordered by a
court, the managing partner has determined in good faith, as of time of the
conduct or omission, that the course of conduct or omission was in the best
interests of the partnership and that the conduct or omission did not constitute
negligence or misconduct. Each
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partnership is authorized to purchase insurance against liabilities asserted
against and expenses incurred by such persons in connection with the
partnership's activities, provided that the partnership will not bear the cost
of that portion of any insurance, other than insurance customary for the
partnership's business, which insures the managing partner for any liability for
which the managing partner may not be indemnified as discussed above. The
drilling program manager has similar rights with respect to insurance, and the
drilling program manager and its affiliates are entitled to similar
indemnification under the drilling program agreement.
The partnership agreements further limit indemnification of the
managing partner by providing that the managing partner, its affiliates and any
person acting as a broker-dealer will not be indemnified for any losses,
liabilities or expenses arising from or out of a violation of federal or state
securities laws unless:
o there has been a successful adjudication on the merits of each
count involving alleged securities law violations as to the
particular indemnitee and the court approves indemnification
of the litigation costs,
o such claims have been dismissed with prejudice on the merits
by a court of competent jurisdiction as to the particular
indemnitee and the court approves indemnification of the
litigation costs, or
o a court of competent jurisdiction approves a settlement of the
claims against a particular indemnitee and finds that
indemnification of the settlement and related costs should be
made.
Insofar as indemnification for liabilities under the Securities Act of
1933 may be permitted to the managing partner by a partnership agreement, the
partnership has been advised that in the opinion of the Securities and Exchange
Commission and certain state securities authorities such indemnification is
against public policy as expressed in the Securities Act of 1933, and is
therefore unenforceable.
RIGHT OF PRESENTMENT
Each investor partner in a partnership may request that the managing
partner purchase for cash all, but not less than all, of that investor partner's
interests subject to certain limitations. The managing partner may also cause
its affiliate to fulfill its obligation to purchase such investor's interests.
Unless extended by the managing partner, partners in a partnership formed in
1999 may make such requests in each of the years 2003 through 2008 and partners
in a partnership formed in 2000 may make such request in each of the years 2004
through 2008. If the interests are subsequently listed on a national securities
exchange or are traded through the National Association of Securities Dealer's
Automated Quotation System or in the over-the-counter market, the right of
presentment may be terminated at the option of the managing partner. Any such
listing could have an adverse effect on the tax consequences of an investment in
interests. See "Tax Aspects - Classification of a Partnership for Tax Purposes"
and "Tax Aspects - General Features of Partnership Taxation - Passive Activity
Loss Limitations." If the obligation of the managing partner or its purchaser
designee to purchase interests from general and limited partners is determined
to violate any existing or future laws, such obligation will be eliminated or
modified appropriately. See "Terms of the Offering -- Right of Presentment."
ASSIGNABILITY OF INTERESTS
Assignability of interests is limited. Except by gift or operation of
law or when consented to by the managing partner, an investor partner in a
partnership may assign only whole interests unless the investor partner owns
less than a whole interest and transfers all his interests to one person or
unless such assignment is to the partnership, the managing partner, an affiliate
of the managing partner, or a third person specified by the managing partner,
and an investor partner must retain at least a whole interest in the event fewer
than all of his interests are assigned to any person other than the partnership,
the managing partner, an affiliate of the managing partner, or a third person
specified by the managing partner. In addition, general and limited partners who
are residents of either the State of California or Iowa are subject to
additional restrictions concerning the amount of their interests that may be
transferred. See "Terms of the Offering - Additional Requirements." interests
may only be assigned to a person otherwise qualified to become a substituted
general partner or a limited partner, as the case may be. In no event may
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any assignment be made which, in the opinion of counsel to that partnership,
would result in the partnership being considered to have been terminated for
purposes of Section 708 of the Internal Revenue Code or might result in a change
in the status of the partnership to a "publicly traded partnership" within the
meaning of Section 7704 of the Internal Revenue Code, unless the managing
partner consents to such an assignment, or which, in the opinion of counsel to
the partnership, may not be effected without registration under the Securities
Act or 1933 or would result in the violation of any applicable state securities
laws. A partnership will not be required to recognize any assignment until the
instrument of assignment has been delivered to the managing partner. In the case
of a mere assignee of interests, the transferring general partner or limited
partner retains all rights other than the right to receive distributions as a
general partner or limited partner. However, an assignee of interests may become
a substituted general partner or limited partner, as the case may be, and thus
be entitled to all of the rights of a general partner or limited partner, only
upon meeting certain conditions, including:
o obtaining the consent of the assignor and the managing partner
to such substitution,
o paying all costs and expenses incurred in connection with such
substitution,
o making certain representations to the managing partner, and
o executing appropriate documents to evidence its agreement to
be bound by all of the terms and provisions of the applicable
partnership agreement.
A partnership will amend its records at least once each calendar
quarter to effect the substitution of substituted partners. In the case of
assignments, where the assignee does not become a substituted partner, a
partnership shall recognize the assignment not later than the last day of the
calendar month following receipt of notice of assignment and required
documentation. The restrictions on transfer contained in the partnership
agreement of a partnership may have the effect of reducing interest in the
partnership as a potential acquisition target or encouraging persons considering
an acquisition or takeover of the partnership to negotiate with the
partnership's managing partner rather than pursue non-negotiated acquisition or
takeover attempts, although no assurance can be given that they will have that
effect.
The interest of the managing partner in a partnership may not be
assigned except in limited circumstances set forth in the partnership agreement,
including without limitation assignments to affiliates of the managing partner
that agree to assume a proportionate share of the obligations of the assigning
managing partner, dispositions arising out of the merger, consolidation,
reorganization, or similar transaction of the managing partner, and any pledge
by the managing partner. The rights and obligations of the managing partner and
its affiliates with respect to a drilling program under the drilling program
agreement may be assigned to affiliates and successors in interest by reason of
merger, consolidation, reorganization, or similar transaction, without the
consent of a majority in interest of the general and limited partners of the
partnership, subject to limitations set forth in the drilling program agreement,
and the managing partner and its affiliates will have the right at any time to
mortgage or pledge its interest in properties of the drilling program.
REMOVAL OR WITHDRAWAL
A majority in interest of the general and limited partners shall have
the right to remove the managing partner and to elect and substitute a new
managing partner. In such event, the removed managing partner shall be required
to offer to sell a minimum of 20% of, and shall have the right to offer to sell
the remaining 80% of such managing partner's interest in the partnership to the
new managing partner at a price and method of payment mutually agreeable to the
removed managing partner and the new managing partner. If the new managing
partner and the removed managing partner are unable to agree within 10 days on
the purchase price of such interest, the new managing partner and the removed
managing partner shall select a mutually agreeable independent expert to
determine such purchase price. In addition, a majority in interest of the
general and limited partners shall have the right to remove Mewbourne Oil
Company as the drilling program manager. In such event, Mewbourne Oil Company
and its affiliates shall have the right to offer to sell up to 100% of their
collective ownership interests in oil and gas leases subject to the drilling
program agreement to the new drilling program manager. The method of payment for
the
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removed managing partner's and Mewbourne Oil Company's interest must be fair and
must protect the solvency and liquidity of the partnership.
In the event the managing partner withdraws or retires from a
partnership and such withdrawal or retirement causes dissolution of the
partnership, a majority in interest of the general and limited partners shall be
entitled to reconstitute the partnership and elect and substitute a new managing
partner. Such new managing partner shall be entitled to acquire the partnership
interest of the retiring managing partner on the same basis and in the same
manner as set forth above. The managing partner may not voluntarily withdraw
from a partnership prior to the later to occur of:
o the completion of the partnership's primary drilling
activities under the related drilling program, and
o the fifth anniversary of the date that general and limited
partners were admitted to the partnership.
In order to exercise its right of withdrawal, the managing partner must
give the general and limited partners at least 120 days' advance written notice.
DISSOLUTION, LIQUIDATION AND TERMINATION
A partnership shall be dissolved upon:
o the occurrence of December 31, 2050,
o the vote or consent in writing of a majority in interest of
the general and limited partners at any time,
o the sale, disposition, or termination of all or substantially
all of the oil and gas leases then owned by the partnership,
o the withdrawal, bankruptcy, insolvency, or dissolution in
certain circumstances of the managing partner, the occurrence
of any other event which would permit a trustee or receiver to
acquire control of the property or affairs of the managing
partner or any other event of withdrawal from the partnership
by the managing partner as provided for by law; provided that
neither the dissolution of the managing partner as a
consequence of merger, consolidation, recapitalization, or
other corporate reorganization effected under the partnership
agreement shall cause dissolution of the partnership,
o the adjudication of insolvency or bankruptcy of the
partnership, or an assignment by the partnership for the
benefit of creditors,
o the withdrawal or retirement of the managing partner, or
o the occurrence of any other event which, under applicable law,
causes the dissolution of the partnership.
If dissolution of a partnership occurs due to the withdrawal or
bankruptcy of a general partner, the partnership shall not be terminated but
shall automatically be reconstituted. Upon dissolution of a partnership for any
reason other than bankruptcy or withdrawal of a general partner, unless it is
reconstituted as provided under "-- Rights and Powers of Partners" above, the
managing partner or a liquidator appointed by the managing partner shall wind up
the affairs of the partnership and make final distribution of its assets. In the
event the managing partner is unable to serve as liquidator, the liquidator
shall be appointed by a majority in interest of the general and limited
partners.
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After making a proper accounting and paying or making provision for the
payment of existing and contingent liabilities, the liquidator of a partnership
shall sell all remaining assets of the partnership for cash at the best price
available therefor and distribute the proceeds of such sales to the partners. In
the case of a sale in liquidation, the liquidator shall adjust the capital
accounts of the partners under the terms of the partnership agreement to account
for all gain and loss on such sales and shall distribute the proceeds of such
sales to the partners in accordance with their respective capital account
balances, as so adjusted. partners in a partnership will not be obligated to
restore any negative balance in their capital accounts after the liquidation of
their interests in a partnership. The distribution of cash or properties to the
partners will constitute a complete distribution to the partners of their
respective interests in that partnership and its property.
In the event of a dissolution and liquidation of a partnership as a
result of an exchange or tender offer, the liquidator may assume the sale of all
remaining assets of the partnership for cash at the respective fair market
values of such assets and then debit or credit each partner's capital account
with its respective share of the hypothetical gains or losses resulting from
such assumed sales in the same manner as such capital account would be debited
or credited on the actual sales of such assets. If such exchange or tender offer
is conducted through a sale of all or substantially all of the assets of a
partnership or is otherwise binding on the partners, the liquidator shall
distribute all securities or other assets received from the sale of the
partnership assets to the partners proportionately based on the partners'
positive capital account balances, as so adjusted. In the event of an exchange
offer that is not binding upon all partners, the liquidator shall then exchange
for securities offered in the exchange or tender offer partnership oil and gas
properties having a fair market value equal to the sum of the positive balances
in the capital accounts, as so adjusted, of the partners who elect to accept the
exchange or tender offer. The liquidator shall distribute such securities to
such accepting partners on a basis reflecting the partners' respective positive
capital account balances, adjusted as provided above.
RECONSTITUTION OF A PARTNERSHIP
In the event the managing partner of a partnership withdraws or retires
from the partnership, directly or as a result of a bankruptcy, dissolution, or
similar event that would dissolve the partnership, a majority in interest of
general and limited partners, acting at a meeting to be held within 90 days
following receipt of written notice of such event from the managing partner,
shall be entitled to reconstitute the partnership and elect and substitute a new
managing partner, which may be the retiring managing partner.
In the event a majority in interest but less than all of the general
and limited partners in a partnership elect to reconstitute the partnership, the
partners' capital accounts shall be adjusted by assuming the sale of all assets
of the partnership for cash at the respective fair market values of such assets
as of the date of dissolution of the partnership and debiting or crediting each
partner's capital account with its respective share of the hypothetical gains or
losses resulting from such assumed sales in the same manner as such capital
account would be debited or credited on the actual sales of such assets.
The new managing partner shall then sell for cash partnership oil and
gas properties having a fair market value equal to the fair market value of all
partnership oil and gas properties times the ratio of the aggregate of the
positive balances in the capital accounts, as so adjusted, of the general and
limited partners that have not elected to reconstitute the partnership and the
retiring managing partner, to the extent the retiring managing partner's
aggregate partnership interest was not purchased by the new managing partner, to
the positive balances of all partners. The new managing partner shall then
distribute such cash to the general and limited partners that have elected not
to reconstitute the partnership and to the managing partner, to such extent, in
proportion to the positive balances of their respective capital accounts.
The new managing partner, on behalf of the partners that have elected
not to form the reconstituted partnership, shall retain for the benefit of the
reconstituted partnership an undivided interest in all oil and gas properties of
the partnership remaining after the distributions provided for above.
The retiring managing partner shall have the right to elect to receive
a distribution in kind of an undivided interest in partnership oil and gas
properties having a fair market value equal to the fair market value of all
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partnership oil and gas properties times the ratio of the positive balance in
the retiring managing partner's capital account to the positive balances of all
partners.
Each general partner of a partnership will covenant not to cause a
dissolution of that partnership by voluntary withdrawal or other voluntary act.
In the event of such a dissolution, however, upon reconstitution of the
partnership, the withdrawing general partner shall remain subject as a general
partner with respect to any liabilities or obligations of the partnership
arising prior to such withdrawal. Upon withdrawal from the partnership, a
general partner is entitled to continue to receive any distributions to which he
is otherwise entitled under the partnership agreement for the period prior to
his withdrawal; however, such general partner shall not be entitled to receive
the fair value of his interest in the partnership as of the date of such
withdrawal based upon his right to share in distributions from the partnership,
and neither the partnership nor the managing partner has any obligation to
repurchase any interest in the partnership from the withdrawing general partner.
The withdrawing general partner will not be entitled to receive any
distributions for the period subsequent to his withdrawal nor shall such general
partner have any rights as an investor partner under the partnership agreement.
The sharing ratios will be recalculated among the general and limited partners
without regard to the withdrawing general partner's capital contribution. If the
partnership is reconstituted due to the bankruptcy of a general partner, the
trustee, receiver, or other successor in interest of the bankrupt general
partner shall become liable for all of the debts and obligations of the bankrupt
general partner.
AMENDMENTS
A majority in interest of the general and limited partners of a
partnership may require the amendment of the partnership agreement without the
consent of the managing partner, except that any amendment which would increase
the liability or duties of any partner, change the contributions required of a
partner, provide for the reallocation of profits, losses, or deductions to the
detriment of a partner, establish any new priority in one or more partners as to
the return of capital contributions or as to profits, losses, deductions, or
distributions to the detriment of a partner or cause the partnership to be taxed
as a corporation, must be approved by such partner before it will be binding
upon him. Minor and conformatory amendments and amendments that do not adversely
affect the general and limited partners in any material respect may be made by
the managing partner without the consent of the general and limited partners.
REPORTS TO PARTNERS
The managing partner will furnish to the general and limited partners
of each partnership semi-annual and annual reports which will contain financial
statements, including a balance sheet and statements of income, partners' equity
and cash flows, all of which shall be prepared in accordance with generally
accepted accounting principles, which statements at fiscal year end will be
audited by an independent certified public accountant. Financial statements
furnished in a partnership's semi-annual reports will not be audited.
Semi-annually, all general and limited partners will also receive a summary
itemization of the transactions between the managing partner or any affiliate of
the managing partner and the partnership showing all items of compensation
received by the managing partner and its affiliates, including without
limitation the average price paid by any affiliate of the managing partner
during the two most recent calendar quarters for oil and gas produced by program
wells purchased by such affiliate and the highest average price paid by any
other substantial purchaser of comparable oil or gas produced in the field where
such program wells are located. Annually beginning with the fiscal year ending
December 31, 2000, as to a partnership formed in 1999, and ending December 2001,
as to a partnership formed in 2000, oil and gas reserve estimates prepared by an
independent petroleum engineer will also be furnished to the general and limited
partners. Annual reports will be provided to the general and limited partners
within 120 days after the close of the partnership fiscal year, and semi-annual
reports will be provided within 75 days after the close of the first six months
of the partnership fiscal year. In addition, the general and limited partners in
a partnership shall receive on a monthly basis while the partnership is
participating in the drilling and completion activities of a drilling program,
reports containing a description of the partnership's acquisition of interests
in prospects, including farmins and farmouts, and the drilling, completion and
abandonment of wells thereon. All general and limited partners will receive a
report containing information necessary for the preparation of their federal
income tax returns and any required state income tax returns by March 15 of each
calendar year or as soon as practicable thereafter. The managing partner will
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109
furnish to the general and limited partners information regarding differences
between tax basis of accounting and the basis of generally accepted accounting
principles in accordance with generally accepted accounting principles. In
addition, the information specified by Form 10-Q, if such report is required to
be filed with the Securities and Exchange Commission, will be furnished to the
general and limited partners within 45 days after the close of each quarterly
fiscal period. General and limited partners in a partnership will also receive
in such monthly reports a summary of the status of wells drilled by the
partnership. The managing partner may provide such other reports and financial
statements as it deems necessary or desirable.
ACCESS TO LIST OF GENERAL AND LIMITED PARTNERS
An alphabetical list of the investor's names, addresses and business
telephone numbers of the general and limited partners in a partnership
identified as general partners or limited partners along with the number of
interests held by each of them will be maintained as a part of the books and
records of the partnership and will be available for inspection by any general
and limited partners or his or her designated agent at the principal office of
the partnership upon the request of an investor partner. The investor list will
be updated at least quarterly to reflect changes in the information contained in
such list. A copy of the investor list for a partnership will be mailed to any
investor partner in the partnership requesting the investor list within ten (10)
days of the request. The copy of the investor list will be printed in
alphabetical order, on white paper, and in a readily readable type size, in no
event smaller than 10-point type. A reasonable charge for copy work may be
charged by the partnership. The purposes for which an investor partner may
request a copy of the investor list include, without limitation, matters
relating to general and limited partners' voting rights under the partnership
agreement and the exercise of general and limited partners' rights under federal
proxy laws. If the managing partner neglects or refuses to exhibit, produce, or
mail a copy of the investor list as requested, the managing partner will be
liable to any investor partner requesting the list for the costs, including
attorneys fees, incurred by that investor partner for compelling the production
of the investor list, and for actual damages suffered by any investor partner by
reason of such refusal or neglect. It shall be a defense that the actual purpose
and reason for the requests for inspection or for a copy of the investor list is
to secure the list of general and limited partners or other information for the
purpose of selling such list or information or copies of such list, or of using
the same for a commercial purpose other than in the interest of the applicant as
an investor partner relative to the affairs of the partnership. The managing
partner may require the investor partner requesting the investor list to
represent that the list is not requested for a commercial purpose unrelated to
the investor partner's interest in the partnership. The above remedies in favor
of an investor partner requesting copies of the investor list are in addition
to, and shall not in any way limit, other remedies available to general and
limited partners under federal law, or the laws of any state.
POWER OF ATTORNEY
In signing the special subscription instructions and the subscription
agreement in the form attached as Exhibit C and Exhibit D to this prospectus,
each investor adopts the terms and provisions of the partnership agreement for
the partnership to which such investor is admitted, including representations
and warranties contained in the partnership agreement, and makes the power of
attorney set forth in Section 10.3 of the partnership agreement. Pursuant to the
partnership agreement, each investor partner of a partnership will appoint the
managing partner as his attorney-in-fact, on his behalf and in his name, to
execute, swear to and file all documents or instruments necessary or desirable:
o to comply with the laws of any state in which the partnership
does business,
o to amend the partnership agreement to admit a new or
substituted general partner or limited partner or make changes
required by amendments thereto adopted by the general and
limited partners,
o to amend the partnership agreement to effect the conversion of
the general partners to limited partners,
o to conduct the business and affairs of the partnership,
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110
o to reflect the agreement of all of the general and limited
partners if the required majority in interest of the general
and limited partners has approved any action under the
partnership agreement and amendments to the partnership
agreement to implement such action, and
o to perform other ministerial acts in connection with the
partnership and its operations, all subject to compliance with
the partnership agreement.
Such appointment shall constitute a power coupled with an interest,
shall not be revocable and shall be effectuated under Section 10.3 of the
partnership agreement by an investor partner's execution of such special
subscription instructions and subscription agreement.
LEGAL OPINIONS
The validity of the interests offered by this prospectus and federal
income tax matters as discussed under "Tax Aspects" in this prospectus has been
passed upon by Vinson & Elkins L.L.P., 3700 Trammel Crow Center, 2001 Ross
Avenue, Dallas, Texas 75201-2975.
EXPERTS
The balance sheet of Mewbourne Development Corporation as of June 30,
1999 and the balance sheet of Mewbourne Energy Partners 00-A, L.P. as of
February 15, 2000 included in this Registration Statement on Form S-1, have been
included in reliance on the reports of PricewaterhouseCoopers LLP, independent
accountants, given on the authority of that firm as experts in accounting and
auditing.
The information included in this Registration Statement on Form S-1
regarding the summary of the reserve report as of December 31, 1999, for
Mewbourne Development Partners 92 GP, Mewbourne Development Partners 93- A,
L.P., Mewbourne Development Partners 93-B, L.P., Mewbourne Development Partners
94-A, L.P., Mewbourne Development Partners 94-B, L.P. Mewbourne Development
Partners 94-C, L.P., Mewbourne Energy Partners 94 Private L.P., Mewbourne Energy
Partners 95-A, L.P., Mewbourne Energy Partners 95-B, L.P., Mewbourne Energy
Partners 96- A, L.P., Mewbourne Energy Partners 97-A, L.P., and Mewbourne Energy
Partners 98-A, L.P. was audited by Garb Grubbs Harris & Associates, Inc. and is
included in this prospectus in reliance upon the report of such firm as experts
with respect to the matters covered by its report and the giving of its report.
WHERE YOU CAN FIND MORE INFORMATION
We have filed a registration statement on behalf of the partnerships
with the Securities and Exchange Commission under the Securities Act of 1933
relating to the interests being offered by this prospectus. This prospectus does
not contain all of the information set forth in the registration statement,
certain portions of which have been omitted pursuant to the rules and
regulations of the Securities and Exchange Commission.
For further information about us, the partnerships and the interests
being offered, please review the registration statement, including the exhibits
that are filed with it. Statements made in the registration statement that
describe documents may not necessarily be complete. We recommend that you also
review the documents that we have filed with the registration statement to
obtain a more complete understanding of those documents. A copy of the
registration statement is available for inspection without charge at the public
reference facilities maintained by the Securities and Exchange Commission at 450
Fifth Street, N.W., Washington, D.C., 20549, 75 Park Place, New York, New York
10007 and Northwestern Atrium Center, 500 West Madison Street, Suite 1400,
Chicago, Illinois 60604. The registration statement may also be obtained from
the Web site maintained by the Securities and Exchange Commission at
http://www.sec.gov. Copies of any materials filed as a part of the registration
statement may be obtained for a fee from the Public Reference Section of the
Securities and Exchange Commission at 450 Fifth Street, N.W., Washington, D.C.,
20549.
The delivery of this prospectus at any time does not imply that the
information contained in this prospectus is correct as of any time subsequent to
the date of this prospectus.
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INDEX TO FINANCIAL STATEMENTS
Financial Statement of Mewbourne Development Corporation:
Report of Independent Accountants............................................................ F1-1
Balance Sheet as of June 30, 1999............................................................ F1-2
Notes to Balance Sheet....................................................................... F1-3
Unaudited Financial Statement of Mewbourne Development Corporation:
Unaudited Balance Sheet as of December 31, 1999.............................................. F2-1
Notes to Unaudited Balance Sheet............................................................. F2-2
Financial Statement of Mewbourne Energy Partners 00-A, L.P.:
Report of Independent Accounts............................................................... F3-1
Balance Sheet as of February 15, 2000........................................................ F3-2
Note to Balance Sheet........................................................................ F3-3
THE FOLLOWING FINANCIAL STATEMENTS INCLUDE THOSE OF THE MANAGING
PARTNER, MEWBOURNE DEVELOPMENT CORPORATION, IN WHICH THE GENERAL AND LIMITED
PARTNERS WILL ACQUIRE NO INTEREST.
112
MEWBOURNE DEVELOPMENT CORPORATION
BALANCE SHEET WITH REPORT
OF INDEPENDENT ACCOUNTANTS
JUNE 30, 1999
113
REPORT OF INDEPENDENT ACCOUNTANTS
September 8, 1999
To the Board of Directors
of Mewbourne Development Corporation
In our opinion, the accompanying balance sheet presents fairly, in all material
respects, the financial position of Mewbourne Development Corporation as of June
30, 1999 in conformity with accounting principles generally accepted in the
United States. This balance sheet is the responsibility of the Company's
management; our responsibility is to express an opinion on this balance sheet
based on our audit. We conducted our audit of this balance sheet in accordance
with auditing standards generally accepted in the United States, which require
that we plan and perform the audit to obtain reasonable assurance about whether
the balance sheet is free of material misstatement. An audit includes examining,
on a test basis, evidence supporting the amounts and disclosures in the balance
sheet, assessing the accounting principles used and significant estimates made
by management, and evaluating the overall balance sheet presentation. We believe
that our audit provides a reasonable basis for the opinion expressed above.
PricewaterhouseCoopers LLP
Dallas, Texas
F1 - 1
114
MEWBOURNE DEVELOPMENT CORPORATION
BALANCE SHEET
JUNE 30, 1999
ASSETS
Current assets:
Cash and cash equivalents $ 1,640,269
Accounts receivable, related party 292,781
-----------
Total current assets 1,933,050
Marketable securities available for sale 1,236,475
Investments in partnerships 111,647
Oil and gas properties - full-cost method, net 4,038,099
-----------
Total assets $ 7,319,271
===========
LIABILITIES AND STOCKHOLDER'S EQUITY
Current liabilities:
Accounts payable, related party $ 95,581
-----------
Deferred income taxes 1,174,610
-----------
Stockholder's equity:
Common stock, $1 par value, 1,000 shares authorized,
issued and outstanding 1,000
Paid-in capital in excess of par value of common stock 1,190,262
Retained earnings 4,704,435
Net unrealized gain on marketable securities available for sale 153,383
-----------
Total stockholder's equity 6,049,080
-----------
Total liabilities and stockholder's equity $ 7,319,271
===========
The accompanying notes are an integral part of this balance sheet
F1 - 2
115
MEWBOURNE DEVELOPMENT CORPORATION
NOTES TO BALANCE SHEET
1. SIGNIFICANT ACCOUNTING POLICIES
FINANCIAL STATEMENT PRESENTATION
Mewbourne Development Corporation (the "Company") is a wholly-owned
subsidiary of Mewbourne Holdings, Inc. (the "Stockholder"). The Company
is principally involved in the exploration and production of oil and gas
in Texas, Oklahoma and New Mexico.
The Company follows the full-cost method of accounting for its oil and
gas activities, all of which are located in the Continental United
States. Under the full-cost method, all productive and nonproductive
costs incurred in the acquisition, exploration and development of oil and
gas properties are capitalized. Depreciation, depletion and amortization
of oil and gas properties is computed on the units-of-production method,
using the proved reserves underlying the oil and gas properties. At June
30, 1999, all capitalized costs were subject to amortization. Gains and
losses on the sale or other disposition of properties are not recognized
unless such adjustments would significantly alter the relationship
between capitalized costs and proved reserves of oil and gas.
Capitalized costs are subject to a ceiling test that limits such costs to
the aggregate of the present value of future net revenues of proved
reserves discounted at 10%, based on current economic and operating
conditions and the lower of cost or fair value of unproved properties.
REVENUE RECOGNITION
Revenue is normally recognized from jointly owned properties as oil and
gas is produced and sold for the Company's account, although the various
interest owners may take more or less than their proportionate ownership
of the production. The Company uses the entitlements method of accounting
for imbalances. There are no material imbalances at June 30, 1999.
MANAGEMENT ESTIMATES
The preparation of financial statements in conformity with generally
accepted accounting principles requires management to make estimates and
assumptions that affect the reported amounts of assets and liabilities
and disclosure of contingent assets and liabilities at the date of the
balance sheet. Actual results could differ from those estimates.
CASH AND CASH EQUIVALENTS
The Company considers all highly liquid investments, those with original
maturities of three months or less at the date of acquisition, to be cash
equivalents.
A substantial portion of the Company's cash and cash equivalents is
maintained in one financial institution.
F1 - 3
116
MEWBOURNE DEVELOPMENT CORPORATION
NOTES TO BALANCE SHEET
1. SIGNIFICANT ACCOUNTING POLICIES (CONTINUED)
SECURITIES
All securities are intended to be held for investment purposes and are
therefore classified as "available for sale" which requires that such
securities be carried at fair value with unrealized holding gains or
losses, net of related income tax effects, recorded as a separate
component of stockholder's equity. Realized gains and losses on sales of
securities are determined utilizing the specific identification method.
INVESTMENTS IN PARTNERSHIPS
The Company is managing partner of several oil and gas partnerships. The
Company accounts for its investment in partnerships using the equity
method of accounting.
2. MARKETABLE SECURITIES
Reconciliation of cost to market value as of June 30, 1999 is as follows:
GROSS
UNREALIZED MARKET
COST GAINS VALUE
---------- ---------- -----------
JUNE 30, 1999
U.S. Treasury Bonds $ 989,084 $ 247,391 $ 1,236,475
---------- ---------- -----------
$ 989,084 $ 247,391 $ 1,236,475
========== ========== ===========
As of June 30, 1999, the cost of U.S. Treasury Bonds includes $582,084 of
accrued interest income.
Included in the Company's securities portfolio as of June 30, 1999 are
debt securities with a market value of $1,236,475 with scheduled
maturities as follows:
Six to ten years $ 707,100
More than ten years 529,375
-----------
$ 1,236,475
===========
For the year ended June 30, 1999, as a result of net unrealized gains and
losses on marketable securities, stockholder's equity decreased by
$57,427, net of deferred income tax of $35,197.
F1 - 4
117
MEWBOURNE DEVELOPMENT CORPORATION
NOTES TO BALANCE SHEET
3. OIL AND GAS PROPERTIES
Oil and gas properties consist of the following as of June 30, 1999:
Proved oil and gas properties $ 8,296,043
Accumulated depreciation, depletion and amortization (4,257,944)
-------------
Net proved oil and gas properties $ 4,038,099
=============
4. INCOME TAXES
Federal income tax expense is calculated on a current basis at the
Stockholder (consolidated) level and is allocated to its subsidiaries
based on their respective taxable income or loss, and a payable or
receivable is established with the Stockholder. As of June 30, 1999,
federal income tax payable to the Stockholder was $0.
In accordance with Statement of Financial Accounting Standards No. 109,
Accounting for Income Taxes, the Company calculates its deferred tax
liability as if it were a separate tax paying entity. Deferred income
taxes are recognized for the tax consequences in future years of
differences between the tax basis of assets and liabilities and their
financial reporting amounts at the balance sheet date based on enacted
tax laws and statutory tax rates applicable to the periods in which the
differences are expected to affect taxable income. Valuation allowances
are established when necessary to reduce deferred tax assets to the
amount expected to be realized.
The deferred tax liability is comprised of the following temporary
differences as of June 30, 1999:
Oil and gas properties $ 1,080,601
Unrealized gain on marketable securities 94,009
-----------
$ 1,174,610
===========
5. RELATED PARTY TRANSACTIONS
Under the terms of an operating agreement, substantially all services and
charges relating to the oil and gas properties in which the Company
invests are billed by and paid to a wholly-owned subsidiary of the
Stockholder as operator of the oil and gas properties.
6. SUPPLEMENTAL OIL AND GAS INFORMATION (UNAUDITED)
The estimates of proved oil and gas reserves utilized in the preparation
of these financial statements were estimated in accordance with
guidelines established by the Securities and Exchange Commission and the
Financial Accounting Standards Board, which require that reserve reports
be prepared under existing economic and operating conditions with no
provision for price and cost escalation except by contractual agreement.
Proved oil and gas reserves are defined as estimated quantities of crude
oil, natural gas, and natural gas liquids which geological and
engineering data demonstrate with reasonable certainty to be recoverable
in future years from known reservoirs under existing economic and
operating conditions. These estimates may change as future information
becomes available. All of the Company's reserves are located onshore in
the Continental United States.
F1 - 5
118
MEWBOURNE DEVELOPMENT CORPORATION
NOTES TO BALANCE SHEET
6. SUPPLEMENTAL OIL AND GAS INFORMATION (UNAUDITED) (CONTINUED)
As of June 30, 1999, the Company had proved oil reserves of 90,064
barrels, and proved gas reserves of 4,824,029 thousand cubic feet (mcf).
Future net cash flows from these reserves are as follows as of June 30,
1999:
Future cash inflows $ 11,583,250
Future production costs (5,189,037)
Future development costs (169,859)
Future income tax expense (1,172,753)
-------------
5,051,601
Discount at 10% (1,973,951)
-------------
Standard measure of discounted future net cash flows from estimated
production of proved oil and gas reserves after
income taxes $ 3,077,650
============
F1 - 6
119
MEWBOURNE DEVELOPMENT CORPORATION
BALANCE SHEET (UNAUDITED)
DECEMBER 31, 1999
120
MEWBOURNE DEVELOPMENT CORPORATION
BALANCE SHEET
(UNAUDITED)
DECEMBER 31, 1999
ASSETS
Current assets:
Cash and cash equivalents $ 1,021,084
Accounts Receivable, related party 325,286
Total current assets 1,346,370
Marketable securities available for sale 1,231,430
Investment in partnerships 124,588
Oil and gas properties-full-cost method, net 5,022,084
-----------
Total assets $ 7,724,472
===========
LIABILITIES AND STOCKHOLDER'S EQUITY
Current liabilities:
Accounts payable, related party $ 0
-----------
Deferred income taxes 1,147,512
-----------
Stockholder's equity:
Common stock, $1.00 par value, 1,000 shares authorized, 1,000
issued and outstanding
Paid-in capital in excess of par value of common stock 1,190,262
Retained earnings 5,262,598
Net unrealized gain on marketable securities available for sale 123,100
-----------
Total stockholder's equity 6,576,960
-----------
Total liabilities and stockholder's equity $ 7,724,472
===========
The accompanying notes are an integral part of this balance sheet.
F2 - 1
121
MEWBOURNE DEVELOPMENT CORPORATION
NOTES TO UNAUDITED BALANCE SHEET
-------------
1. SIGNIFICANT ACCOUNTING POLICIES
FINANCIAL STATEMENT PRESENTATION
Mewbourne Development Corporation (the "Company"), is a wholly-owned
subsidiary of Mewbourne Holdings, Inc. (the "Stockholder"). The Company
is principally involved in the exploration and production of oil and gas
in Texas, Oklahoma, and New Mexico.
The Company follows the full-cost method of accounting for its oil and
gas activities, all of which are located in the Continental United
States. Under the full-cost method, all productive and nonproductive
costs incurred in the acquisition, exploration and development of oil and
gas properties are capitalized. All such costs are directly identified
with acquisition, exploration and development activities and do not
include any costs related to production, general corporate overhead, or
similar activities. Depreciation, depletion, and amortization of oil and
gas properties is computed on the units-of-production method, using the
proved reserves underlying the oil and gas properties. Gains and losses
on the sale or other disposition of properties are not recognized unless
such adjustments would significantly alter the relationship between
capitalized costs and proved reserves of oil and gas. Capitalized costs
in unproved properties are not amortized until proved reserves associated
with the property can be determined or until impairment occurs. At
December 31, 1999, $347,396 of unevaluated costs were excluded from
amortization.
Capitalized costs are subject to a ceiling test that limits such costs to
the aggregate of the present value of future net revenues of proved
reserves discounted at 10%, based on operating conditions, oil and gas
prices at the balance sheet date, and the lower of cost or fair value of
unproved properties.
REVENUE RECOGNITION
Revenue is normally recognized from jointly owned properties as oil and
gas is produced and sold for the Company's account, although the various
interest owners may take more or less than their proportionate ownership
of the production. The Company uses the entitlements method of accounting
for imbalances. There are no material imbalances at December 31, 1999.
MANAGEMENT ESTIMATES
The preparation of financial statements in conformity with generally
accepted accounting principles requires management to make estimates and
assumptions that affect the reported amounts of assets and liabilities
and disclosure of contingent assets and liabilities at the date of the
financial statements and the reported amounts of revenues and expenses
during the reporting period. Actual results could differ from those
estimates.
CASH AND CASH EQUIVALENTS
The Company considers all highly liquid investments, those with original
maturities of three months or less to be cash equivalents. A substantial
portion of the Company's cash and cash equivalents is maintained in one
financial institution.
F2 - 2
122
MEWBOURNE DEVELOPMENT CORPORATION
NOTES TO UNAUDITED BALANCE SHEET
-------------
1. SIGNIFICANT ACCOUNTING POLICIES (CONTINUED)
SECURITIES
All securities are intended to be held for investment purposes and are
therefore classified as "available for sale." Accordingly, such
securities are carried at fair value with unrealized holding gains or
losses, net of related income tax effects, recorded as a separate
component of stockholder's equity. Realized gains and losses on sales of
securities are determined utilizing the specific identification method.
INVESTMENTS IN PARTNERSHIPS
The Company is Managing Partner of several oil and gas partnerships. The
Company accounts for its investments in partnerships using the equity
method of accounting.
2. MARKETABLE SECURITIES
Reconciliation of cost to market value as of December 31, 1999 is as
follows:
GROSS
UNREALIZED MARKET
COST GAINS VALUE
----------- ----------- -----------
U.S. Treasury Bonds $ 1,032,882 $ 198,548 $ 1,231,430
As of December 31, 1999, the cost of U.S. Treasury Bonds includes
$625,882 of accrued interest income, of which $43,798 was recognized for
the period ended December 31, 1999. All U.S. Treasury Bonds have maturity
dates between five to twenty years.
Included in the Company's securities portfolio as of December 31, 1999
are debt securities with a market value of $1,231,430 with scheduled
maturities as follows:
Six to ten years $ 711,180
More than ten years 520,250
-----------
$ 1,231,430
===========
3. OIL AND GAS PROPERTIES
Oil and gas properties consist of the following as of December 31, 1999:
Unproved oil and gas properties $ 347,396
Proved oil and gas properties 9,240,573
Accumulated depreciation, depletion, and amortization (4,565,887)
------------
Net oil and gas properties $ 5,022,082
============
F2 - 3
123
MEWBOURNE DEVELOPMENT CORPORATION
NOTES TO UNAUDITED BALANCE SHEET
-------------
4. INCOME TAXES
Federal income tax expense calculated on a current basis at the
Stockholder (consolidated) level is allocated to its subsidiaries based
on their respective taxable income or loss, and a payable or receivable
is established with the stockholder. As of December 31, 1999, federal
income tax payable to shareholders was zero.
In accordance with Statement of Financial Accounting Standards No. 109,
Accounting for Income Taxes, the Company calculates its deferred tax
liability as if it were a separate tax paying entity. Deferred income
taxes are recognized for the tax consequences in future years of
differences between the tax basis of assets and liabilities and their
financial reporting amounts at the balance sheet date based on enacted
tax laws and statutory tax rates applicable to the periods in which the
differences are expected to affect taxable income. Valuation allowances
are established when necessary to reduce deferred tax assets to the
amount expected to be realized.
As of December 31, 1999, the Company's deferred tax liability is
comprised of the following temporary differences:
Oil and gas properties $ 1,072,063
Unrealized gain on marketable securities 75,449
-----------
$ 1,147,512
===========
5. RELATED PARTY TRANSACTIONS
Under the terms of an operating agreement, substantially all services and
charges relating to the oil and gas properties in which the Company
invests are billed by and paid to a wholly-owned subsidiary of the
Stockholder as operator of the oil and gas properties.
6. SUPPLEMENTAL OIL AND GAS INFORMATION (UNAUDITED)
The estimates of proved oil and gas reserves utilized in the preparation
of the balance sheet were estimated in accordance with guidelines
established by the Securities and Exchange Commission and the Financial
Accounting Standards Board, which require that reserve reports be
prepared using oil and gas prices and operating conditions at the balance
sheet date with no provision for price and cost escalation except by
contractual agreement. Proved oil and gas reserves are defined as
estimated quantities of crude oil, natural gas, and natural gas liquids
which geological and engineering data demonstrate with reasonable
certainty to be recoverable in future years from known reservoirs under
existing economic and operating conditions. These estimates may change as
future information becomes available. All of the Company's reserves are
located onshore in the continental United States.
As of December 31, 1999, the Company had proved oil reserves of 100,828
barrels and proved gas reserves of 5,516,047 thousand cubic feet (mcf).
Future net revenues and the present value of these reserves are as
follows as of December 31, 1999:
Future cash inflows $ 14,279,700
Future production costs (6,331,933)
Future development costs (317,173)
Future income tax expense (1,294,524)
------------
6,336,070
Discount at 10% (2,568,903)
------------
Standard measure of discounted future net cash flows
from estimated production of proved oil and gas
reserves after income taxes $ 3,767,167
============
F2 - 4
124
MEWBOURNE ENERGY
PARTNERS 00-A, L.P.
BALANCE SHEET WITH REPORT OF
INDEPENDENT ACCOUNTANTS
FEBRUARY 15, 2000 (DATE OF INCEPTION)
125
REPORT OF INDEPENDENT ACCOUNTANTS
February 28, 2000
To the Board of Directors
Mewbourne Development Corporation
In our opinion, the accompanying balance sheet presents fairly, in all material
respects, the financial position of Mewbourne Energy Partners 00-A, L.P. as of
February 15, 2000 (date of inception) in conformity with accounting principles
generally accepted in the United States. This balance sheet is the
responsibility of the Company's management; our responsibility is to express an
opinion on this balance sheet based on our audit. We conducted our audit in
accordance with auditing standards generally accepted in the United States,
which require that we plan and perform the audit to obtain reasonable assurance
about whether the balance sheet is free of material misstatement. An audit
includes examining, on a test basis, evidence supporting the amounts and
disclosures in the balance sheet, assessing the accounting principles used and
significant estimates made by management, and evaluating the overall balance
sheet presentation. We believe that our audit provides a reasonable basis for
the opinion expressed above.
PricewaterhouseCoopers LLP
Dallas, Texas
F3 - 1
126
MEWBOURNE ENERGY PARTNERS 00-A, L.P.
BALANCE SHEET
FEBRUARY 15, 2000
ASSETS
Cash $ 100
-----
Total assets $ 100
-----
PARTNERS' CAPITAL
Partners' capital $ 100
-----
Total partners' capital $ 100
-----
The accompanying note is an integral part of this balance sheet.
F3 - 2
127
MEWBOURNE ENERGY PARTNERS 00-A, L.P.
NOTE TO BALANCE SHEET
1. ORGANIZATION
Mewbourne Energy Partners 00-A, L.P. (the "Partnership") was formed on
February 15, 2000. The Partnership was organized to offer partnership
interests and to participate in a program consisting of the acquisition,
drilling and development of oil and gas prospects. The offering of
limited and general partner interest has not begun; as such, the
Partnership's operations have not commenced. Mewbourne Development
Corporation ("MDC") serves as managing partner.
F3 - 3
128
EXHIBIT C
SPECIAL SUBSCRIPTION INSTRUCTIONS
MEWBOURNE ENERGY 99-00 DRILLING PROGRAMS
129
[THIS PAGE INTENTIONALLY LEFT BLANK]
130
SPECIAL SUBSCRIPTION INSTRUCTIONS
Mewbourne Energy 99-00 Drilling Programs
Checks for Interests should he made payable to "Bank of America of Texas,
Escrow Agent for Mewbourne" and should be given to the subscriber's broker for
submission to the Escrow Agent. The minimum subscription is $10,000 (ten
Interests); additional purchases above such minimum may be made in increments of
$1,000 (one Interest). In the event that a subscriber purchases Interests in a
particular Partnership on more than one occasion during an offering period, the
minimum purchase on each occasion is five Interests. THE FOLLOWING SPECIAL
SUBSCRIPTION INSTRUCTIONS ARE IN ADDITION TO THE INSTRUCTIONS SET FORTH IN THE
SUBSCRIPTION AGREEMENT ATTACHED AS EXHIBIT D TO THE PROSPECTUS.
TRANSFER OF INTERESTS:
o If a resident of MISSOURI, I am aware that the Commissioner of
Securities of Missouri classifies the securities (the Interests) as
being ineligible for any transactional exemption under the Missouri
Uniform Securities Act (Section 409.402(b), RsMo. 1969). Therefore,
unless the securities are again registered under such Act, the offer
for sale or resale thereof in the State of Missouri may be subject to
the sanctions of the Act.
SUBSCRIBERS OF INTERESTS:
o If a resident of MICHIGAN, in addition to the requirement set forth
below, I hereby represent that the investment in the Partnerships does
not exceed ten percent of my individual or joint net worth (exclusive
of home, home furnishings and automobiles).
o If a resident of NEW HAMPSHIRE, I hereby represent that I have (a) an
individual net worth of at least $250,000 (exclusive of home, home
furnishings, and automobiles), or (b) an individual net worth of at
least $125,000 (exclusive of home, home furnishings, and automobiles)
and $50,000 of taxable income.
o If a resident of TENNESSEE, I hereby represent that I have (a) an
individual net worth of at least $250,000 (exclusive of home, home
furnishings and automobiles) and had during the last tax year and
estimate that I will have during the current tax year, a gross income
of at least $65,000, or (b) a net worth of at least $500,000
(exclusive of home, home furnishings and automobiles).
SUBSCRIBERS OF LIMITED PARTNER INTERESTS:
o If a resident of ARIZONA and investing as a Limited Partner of the
Partnership, I have either: (a) a net worth of at least $225,000
(exclusive of home, furnishings and automobiles) or (b) have a net
worth of at least $75,000 and an annual gross income of at least
$75,000 (exclusive of home, furnishings and automobiles). I hereby
represent that the investment in the Partnerships does not represent
more than ten percent of my net worth, less the value of my other
investments in limited partnership interests.
SUBSCRIBERS OF GENERAL PARTNER INTERESTS:
o If a resident of ALABAMA, ARIZONA, IOWA, KANSAS, MAINE, MASSACHUSETTS,
MISSISSIPPI, MISSOURI, NEW MEXICO, NORTH CAROLINA, OHIO, OREGON,
PENNSYLVANIA, SOUTH CAROLINA, SOUTH DAKOTA, TENNESSEE, TEXAS, UTAH,
VIRGINIA, WASHINGTON or WEST VIRGINIA, and investing as a General
Partner of the Partnership, I have either (a) a minimum net worth of
$225,000 without regard to the investment in a Partnership (exclusive
of home, home furnishings and automobiles) and as to the residents of
Alabama, Maine, Massachusetts, North Carolina, Pennsylvania, South
Carolina, Tennessee, Texas, Utah, Virginia, Washington and West
Virginia a minimum annual gross income of $100,000 for the current
year and for the two previous years and as to residents of Arizona,
Iowa, Kansas, Michigan, Mississippi, Missouri, Ohio, Oregon and South
Dakota income of $60,000 or more for the previous year and the
expectation of an annual taxable income of $60,000 or more for the
current year and for the next succeeding year); or (b) a minimum net
worth in excess of $1,000,000, inclusive of home, home furnishings and
automobiles; or (c) a minimum net worth of $500,000 (exclusive of
home, home furnishings and automobiles) or (d) a minimum annual gross
income of $200,000 in the current year and the two previous years.
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131
ATTENTION PENNSYLVANIA RESIDENTS
o Because the minimum closing amount is less than $2,000,000, you are
cautioned to carefully evaluate the Partnership's ability to fully
accomplish its stated objectives and to inquire as to the current
dollar volume of program subscriptions.
ATTENTION CALIFORNIA INVESTORS
o Subscriptions for Limited Partner Interests: If a resident of
CALIFORNIA and subscribing for Limited Partner Interests, I have
either (a) a net worth of at least $250,000 or more (exclusive of
home, home furnishings and automobiles) and had during the last tax
year or estimates that he/she will have during the current tax year, a
gross annual income of $65,000 or more, or (b) a net worth of $500,000
or more (exclusive of home, home furnishings and automobiles).
o Subscriptions for General Partner Interests: If a resident of
CALIFORNIA and subscribing for General Partner Interests, I have
either (a) a net worth of at least $250,000 or more (exclusive of
home, home furnishings and automobiles) and had during the last tax
year, or estimates that he/she will have during the current tax year,
a gross annual income of $120,000 or more, or (b) a net worth of
$500,000 or more (exclusive of home, home furnishings and
automobiles), or (c) a net worth of $1,000,000 or more (inclusive of
home, home furnishings and automobiles), or (d) had during the last
tax year, or estimates that he/she will have during the current tax
year, a gross annual income of $200,000 or more.
o As a condition of qualification of the Interests for sale in the State
of CALIFORNIA, each California subscriber, through the execution of
the Subscription Agreement, acknowledges his/her understanding that
the California Department of Corporations has adopted certain
regulations and guidelines which apply to oil and gas interests to the
public in the State of California and that the offering may not comply
with all of the rules set forth in Title 10 of the California
Administrative Code, including rules pertaining to compensation,
democracy rights and reports. Even in light of such non-compliance, I
affirmatively state that I still want to invest in the Partnership.
o Assignability or transfer of Interests must be limited so that no
assignee or assignor, transferee or transferor may hold less than
$5,000 in Interests.
o A RESIDENT OF CALIFORNIA SHOULD BE AWARE THAT IT IS UNLAWFUL TO
CONSUMMATE A SALE OR TRANSFER OF THIS SECURITY, OR ANY INTEREST
THEREIN, OR TO RECEIVE ANY CONSIDERATION THEREFOR, WITHOUT THE PRIOR
WRITTEN CONSENT OF THE COMMISSIONER OF CORPORATIONS OF THE STATE OF
CALIFORNIA, EXCEPT AS PERMITTED IN THE COMMISSIONER'S RULES.
CERTIFICATES REPRESENTING INTERESTS IN THE MEWBOURNE DEVELOPMENT 99-00
DRILLING PROGRAM WILL BEAR A LEGEND STATING THIS RESTRICTION ON
TRANSFER.
As a condition of qualification of the Interests for sale in the State of
California, the following rule is hereby delivered to each California purchase.
California Administrative Code, Title 10, CH. 3. Rule 260.141.11.
Restriction on transfer. (a) The issuer of any security upon which a restriction
on transfer has been imposed pursuant to Sections 260.102.6, 260.141.10, and
260.534 shall cause a copy of this section to be delivered to each issuee or
transferee of such security at the time the certificate evidencing the security
is delivered to the issuee or transferee.
(b) It is unlawful for the holder of any such security to consummate a sale
or transfer of such security, or any interest therein, without the prior written
consent of the Commissioner (until this condition is removed pursuant to Section
260.141.12 of these rules), except:
(1) to the issuer;
(2) pursuant to the order or process of any court;
C-2
132
(3) to any person described in subdivision (i) of Section 25102 of the
Code or Section 260.105.14 of these rules;
(4) to the transferor's ancestors, descendants or spouse, or any
custodian or trustee for the account of the transferor or the transferor's
ancestors, descendants, or spouse; or to a transferee by a trustee or
custodian for the account of the transferee or the transferee's ancestors,
descendants or spouse;
(5) to the holders of securities of the same class of the same issuer;
(6) by way of gift or donation inter vivos or on death;
(7) by or through a broker-dealer licensed under the Code (either
acting as such or as a finder) to a resident of a foreign state, territory
or country who is neither domiciled in this state to the knowledge of the
broker-dealer, nor actually present in this state if the sale of such
securities is not in violation of any securities law of the foreign state,
territory or country concerned;
(8) to a broker-dealer licensed under the Code in a principal
transaction, or as an underwriter or member of an underwriting syndicate or
selling group;
(9) if the interest sold or transferred is a pledge or other lien
given by the purchaser to the seller upon a sale of the security for which
the Commissioner's written consent is obtained or under this rule not
required;
(10) by way of a sale qualified under Section 25111, 25112, 25113 or
25121 of the Code, of the securities to be transferred, provided that no
order under Section 25140 or subdivision (a) of Section 25143 is in effect
with respect to such qualification;
(11) by a corporation to a wholly-owned subsidiary of such
corporation, or by a wholly-owned subsidiary of a corporation to such
corporation;
(12) by way of an exchange qualified under Section 25111,25112 or
25113 of the Code, provided that no order under Section 25140 or
subdivision (a) of Section 25143 is in effect with respect to such
qualification;
(13) between residents of foreign states, territories or countries who
are neither domiciled nor actually present in this state;
(14) to the State Controller pursuant to the Unclaimed Property Law or
to the administrator of the unclaimed property law of another state;
(15) by the State Controller pursuant to the Unclaimed Property Law or
by the administrator of the unclaimed property law of another state if, in
either such case, such person (i) discloses to potential purchasers at the
sale that transfer of the securities is restricted under this rule, (ii)
delivers to each purchaser a copy of this rule, and (iii) advises the
Commissioner of the name of each purchaser;
(16) by a trustee to a successor trustee when such transfer does not
involve a change in the beneficial ownership of the securities; or
(17) by way of an offer and sale of outstanding securities in an
issuer transaction that is subject to the qualification requirement of
Section 25110 of the Code but exempt from that qualification requirement by
subdivision (f) of Section 25102;
provided that any such transfer is on the condition that any certificate
evidencing the security issued to such transferee shall contain the legend
required by this section.
C-3
133
(c) The certificates representing all such securities subject to such a
restriction on transfer, whether upon initial issuance or upon any transfer
thereof, shall bear on their face a legend, prominently stamped or printed
thereon in capital letters of not less than 10-point size, reading as follows:
"IT IS UNLAWFUL TO CONSUMMATE A SALE OR TRANSFER OF THIS SECURITY, OR
ANY INTEREST THEREIN, OR TO RECEIVE ANY CONSIDERATION THEREFOR, WITHOUT THE
PRIOR WRITTEN CONSENT OF THE COMMISSIONER OF CORPORATIONS OF THE STATE OF
CALIFORNIA, EXCEPT AS PERMITTED IN THE COMMISSIONER'S RULES."
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134
EXHIBIT D
SUBSCRIPTION AGREEMENT
MEWBOURNE ENERGY 99-00 DRILLING PROGRAMS
135
SUBSCRIPTION AGREEMENT
Mewbourne Energy 99-00 Drilling Programs
The undersigned hereby subscribes for, and if accepted by Mewbourne
Development Corporation (the "Managing Partner"), in its capacity as managing
general partner of the limited partnership indicated below (the "Partnership"),
agrees to purchase that certain dollar amount indicated below of Interests at
$1,000 per Interest. Enclosed please find my check in the amount of $______ made
payable to "Bank of America of Texas, Escrow Agent for Mewbourne." Defined terms
used and not defined herein shall have the meaning assigned to such terms in the
Agreement of Partnership for the Partnership, dated , 2000 (the "Agreement of
Partnership"). With respect to this purchase, being aware that a broker may sell
to me only if I qualify according to the express standards stated herein in the
Special Subscription Instructions attached as Exhibit C to the Prospectus and in
the Prospectus, I hereby:
INITIAL
- -------
(a) Acknowledge that I have received a copy of the
- ----- Prospectus for the Partnership.
(b) Represent that I have either (a) a minimum annual
- ----- gross income of $60,000 and a minimum net worth of $60,000
(exclusive of home, home furnishings and automobiles; or (b) a
minimum net worth of $225,000 (exclusive of home, home
furnishings and automobiles).
(c) If a resident of ALABAMA, ARIZONA, CALIFORNIA,
- ----- IOWA, KANSAS, MAINE, MASSACHUSETTS, MICHIGAN, MISSISSIPPI,
MISSOURI, NEW HAMPSHIRE, NEW MEXICO, NORTH CAROLINA, OHIO,
OREGON, PENNSYLVANIA, SOUTH CAROLINA, SOUTH DAKOTA, TENNESSEE,
TEXAS, UTAH, VIRGINIA, WASHINGTON OR WEST VIRGINIA, represent
that I am aware of and satisfy the additional suitability and
other requirements stated in Exhibit C to the Prospectus.
(d) Represent that I am an "Eligible Citizen" as
- ----- defined in the Prospectus.
(e) Represent that (i) if an individual, I am over 21
- ----- years of age, (ii) if an association, all of the members are
of such age, (iii) if a corporation, it is authorized and
otherwise duly qualified to hold an interest in the
Partnership and to hold Leases and interests therein and is
(or at the request of the Managing Partner will promptly
become) qualified to do business in each jurisdiction in which
the business or activities of the Partnership necessitate such
qualification, and (iv) if a fiduciary, I would qualify under
clauses (i), (ii) or (iii) of this Section (f) and is acting
for a person who would so qualify or for a person who would so
qualify except that such person is under 21 years of age.
(f) Except as set forth in (g) below, represent that
- ----- I am purchasing Interests for my own account and will be sole
party in interest with respect to the acquired Interests and
will have all legal, beneficial and equitable rights in such
Interests.
(g) If a fiduciary, represent that (i) I am
- ----- purchasing for a person or entity having the appropriate
income and/or net worth and is an "Eligible Citizen" as
specified in (b) through (f) above, (ii) if I am the donor of
the funds for investment in the Partnership, I have the
appropriate income and/or net worth specified in this
Subscription Agreement, and (iv) if either the beneficiary of
the fiduciary account is, or I am, a resident of NORTH
CAROLINA, the suitability standards set forth in this
Subscription Agreement are met by me or the fiduciary account
or by the donor who directly or indirectly supplies the funds
for the investment in the Interests.
(h) Certify that the number shown as my Social
- ----- Security or Taxpayer Identification Number on the signature
page is correct and that I am not subject to backup
withholding under the Code.
(i) Represent that I have the right, power and
- ----- authority to enter into this Subscription Agreement, the
Agreement of Partnership, to become an Investor Partner and to
perform my obligations thereunder.
(j) Agree that my completion and execution of this
- ----- Subscription Agreement also constitutes my execution of the
Agreement of Partnership and the Certificate of Limited
Partnership of the Partnership, and if this Subscription is
accepted by the Managing Partner in its sole discretion, I
will become a Limited Partner or General Partner in the
Partnership and will be bound by the terms and provisions of
the Agreement of Partnership of the Partnership.
D-1
136
- ----- (k) Agree that the Managing Partner in its sole and
absolute discretion shall have the right not to form the
Partnership and to terminate the offering of Interests therein
at any time and to reject this subscription.
(l) Make the Power of Attorney set forth in Section
- ----- 10.2 of the Agreement of Partnership of the Partnership.
(m) Unless it is indicated on the next page that I am
- ----- a foreign person or foreign entity, (i) certify that, if the
subscriber is an individual, the subscriber is not a
nonresident alien for the purposes of United States federal
income taxation or, if the subscriber is a corporation,
partnership, trust, or estate, the subscriber is not a foreign
corporation, foreign partnership, foreign trust, or foreign
estate (as those terms are defined in the Code and regulations
promulgated thereunder), (ii) declare under penalties of
perjury that the foregoing certification and the name,
identifying number, home address (in the case of an
individual) or office address (in the case of an entity), and
place of incorporation (in the case of a corporation) of the
subscriber is to the best of my knowledge and belief true,
correct, and complete, and (iii) agree to inform the Managing
Partner if the subscriber becomes a nonresident alien or a
foreign person at any time during the three year period
immediately following the date of this Subscription Agreement.
(n) Agree not to file the statement described in
- ----- Section 6224(c)(3)(B) of the Internal Revenue Code prohibiting
the Managing Partner, as the tax matters partner for the
Partnership, from entering into a settlement on his behalf
with respect to partnership items (as such term is defined in
Code Section 6231(a)(3)) of the Partnership.
(o) Agree that the Managing Partner is authorized to
- ----- file a copy of this Subscription Agreement (or pertinent
portions hereof) with the Internal Revenue Service pursuant to
Section 6224(b) of the Code if necessary to perfect my waiver
of rights under this Subscription Agreement.
(p) Agree that the foregoing representations,
- ----- warranties and agreements shall remain true and accurate
during the term of the Partnership, and I will neither take
action nor permit action to be taken which would cause any of
them to become untrue or inaccurate. In the event that I
become aware that any such representation, warranty or
agreement has become untrue or inaccurate at any time, I shall
immediately notify the Managing Partner and provide the
Managing Partner with such other information and statements
and grant to the Managing Partner such power of attorney as
the Managing Partner may request.
(q) Acknowledge that it is anticipated that there
- ----- will not be any market for resale of the Interests subscribed
hereby and that assignment of such Interests is subject to
certain restrictions described in "Summary of Partnership
Agreement and Program Agreement -- Assignability of Interests"
in the Prospectus; accordingly, the investment subscribed to
hereby is not liquid.
THE UNDERSIGNED MUST INITIAL EACH OF THE ABOVE REPRESENTATIONS IN THE
SPACE PROVIDED.
NOTHING HEREIN SHALL BE DEEMED A WAIVER OF ANY RIGHTS OF ACTION WHICH I
MAY HAVE UNDER ANY APPLICABLE FEDERAL OR STATE SECURITIES LAW.
(1) The purchase of Interests as a General Partner involves a
risk of unlimited liability to the extent that the Partnership's
liabilities exceed its insurance proceeds, the Partnership's assets,
and indemnification by the Managing Partner, as described in "Risk
Factors" in the Prospectus.
(2) The NASD requires the Soliciting Dealer or registered
representative to inform potential investors of all pertinent facts
relating to the liquidity and marketability of the Interests, including
the following: (i) the risks involved in the offering, including the
speculative nature of the investment and the speculative nature of
drilling for oil and gas; (ii) the financial hazards involved in the
offering, including the risk of losing my entire investment; (iii) the
lack of liquidity of this investment; (iv) the restrictions of
transferability of the Interests; and (v) the tax consequences of the
investment.
Subscriptions shall be accepted or rejected by the Managing Partner
within 30 days of their receipt; if rejected, all funds shall be returned to the
subscriber immediately. Any amendment to this Subscription Agreement shall be
made only upon execution of a written consent by me, the Managing Partner, and
the Partnership. This Subscription Agreement shall be governed and enforced in
accordance with the laws of the State of Texas. The representations, warranties,
and covenants contained herein will inure to the benefit of, and be binding upon
me, the Managing Partner, the Partnership, and my and their respective
successors, heirs, representatives, and assigns.
D-2
137
SEND SUBSCRIPTION AND CHECK TO:
BANK OF AMERICA OF TEXAS, N.A., ESCROW AGENT
3301 GOLDEN ROAD
TYLER, TEXAS 75701
(903) 510-5041
D-3
138
TO BE COMPLETED BY APPLICANT(S)
The undersigned subscribes to the Partnership indicated below in the
amount indicated below. The minimum subscription per Partnership is $10,000 (ten
Interests), with additional amounts available in $1,000 increments (one
Interest).
SUBSCRIPTION: $______________ PARTNERSHIP: Mewbourne Energy Partners ____-A, L.P.
Type of Interests Purchased [ ] General Partner Interes IF NO SELECTION IS MADE, THE PARTNERSHIP CANNOT ACCEPT YOUR
SUBSCRIPTION AND WILL HAVE TO RETURN THIS SUBSCRIPTION
[ ] Limited Partner Interes AGREEMENT AND YOUR MONEY TO YOU.
Check one:
Individual Employee Benefit Plan as defined in Sect Keogh Plan (HR-10)
- --- --- 3(3) of ERISA ---
Community Property IRA, IRA Rollover or SEP
- --- --- ---
Tenants in Common Tax/Partnership Other Qualified Plan
- --- --- ---
Joint tenants with right of Corporation ______________________ Tax-exempt under 501(c)(3)
- --- survivorship --- (Place of Incorporation) ---
Foreign person or entity Other (_____________) please specify
--- ---
- -----------------------------------------------------------------------------------------------------------------------------------
Print Name(s) in which Interests should be registered
- -----------------------------------------------------------------------------------------------------------------------------------
Print Name(s) in which Interests should be registered
- -----------------------------------------------------------------------------------------------------------------------------------
Mailing Address
- ---------------------------------------------------------- ----------- -----------
City State Investor's State of Residence
- ------------------------ ------------------------ ------------------------------
Zip Code SS#/Tax ID# Phone No.
- ------------------------------------------------
Account Number (if applicable)
CUSTODIAN OR CHECKS PAYABLE TO OTHERS (OPTIONAL)
Checks will be payable to the registration name and address shown above, unless
otherwise specified below.
- -----------------------------------------------------------------------------------------------------------------------------------
Person/Entity
- -----------------------------------------------------------------------------------------------------------------------------------
For the Benefit of
- -----------------------------------------------------------------------------------------------------------------------------------
Acct. No.
- -----------------------------------------------------------------------------------------------------------------------------------
Mailing Address for Distribution Checks
- ----------------------------------------------- ----------- ----------- ---------------------------------------
City State Zip Code Tax ID #
SIGNATURE AND POWER OF ATTORNEY
I hereby appoint Mewbourne Development Corporation, with full power of
substitution, my true and lawful attorney to execute, file, swear to and record
any Certificate(s) of Limited Partnership or amendments thereto (including but
not limited to any amendments filed for the purpose of the admission of any
substituted Partners) or cancellation thereof, including any other instruments
which may be required by law in any jurisdiction to permit qualification of the
Partnership as a limited partnership or for any other purpose necessary to
implement the Agreement of Partnership, and as more fully described in Article X
of the Agreement of Partnership.
I AM AWARE OF, AGREE AND SATISFY THE REPRESENTATIONS, AGREEMENTS AND
SUITABILITY REQUIREMENTS IN THIS SUBSCRIPTION AGREEMENT AND IN THE SPECIAL
SUBSCRIPTION INSTRUCTIONS ATTACHED AS EXHIBIT C TO THE PROSPECTUS.
- -------------------------------------- -------------------------------------
Signature of Applicant or Signature of Joint Applicant or
Authorized Representative* Authorized Representative*
Date: Date:
--------------------------------- --------------------------------
* An "Authorized Representative" may not execute this subscription agreement for
individual investors residing in the following jurisdictions: MICHIGAN, NORTH
CAROLINA, OHIO, PENNSYLVANIA, AND TENNESSEE.
SUBSCRIBERS ARE URGED TO CAREFULLY READ THE REPRESENTATIONS, AGREEMENTS AND
SUITABILITY REQUIREMENTS SET FORTH HEREIN AND IN EXHIBIT D TO THE PROSPECTUS
BEFORE EXECUTING THIS AGREEMENT.
D-4
139
A SUBSCRIBER MUST INITIAL IN THE SPACE PROVIDED EACH OF THE REPRESENTATIONS MADE
BY THE SUBSCRIBER HEREIN.
FOR SOLICITING DEALER USE ONLY
- -----------------------------------------------------------------------------------------------------------------------------------
Firm
- ---------------------------------------------------- ---------------------------------------------------------------------
Branch Office Address Phone No.
- --------------------------------------- -------- -------------------
City State Zip Code
- ------------------------------------------------------------
Representative's Number
- ------------------------------------------------------------
Signature of Registered Representative
- ---------------------------------------------------- ---------------------------------------------------------------------
Print Name of Registered Representative Authorized Signature for Branch Manager+
+By signing on this line I hereby represent that I have discharged my
affirmative obligations under Sections 3 and 4 of Rule 2810 of the NASD Rules of
Fair Practice and that I have reasonable grounds to believe, on the basis of
information obtained from the applicant concerning his/her investment
objectives, other investments, financial situation and needs, and any other
information known by the member, that: (i) the applicant is or will be in a
financial position appropriate to enable him to realize to a significant extent
the benefits described in the Prospectus, including the tax benefits; (ii) the
applicant has a fair market net worth sufficient to sustain the risks inherent
in the Limited Partnership, including loss of the investment and lack of
liquidity; (iii) an investment in the Partnership is otherwise suitable for the
applicant; and (iv) the applicant, along with one or more representatives,
advisors or agents has the knowledge and experience in financial matters to be
capable of evaluating the merits and risks of the offering. If this purchase is
being executed in a discretionary account, the member has received prior written
approval of the purchase by the customer. The member has informed the applicant
of all pertinent facts relating to the liquidity and marketability of the
Interests in the Partnership during the term of the investment, of the risks of
unlimited liability regarding an investment as a General Partner, and of the
passive loss limitations for tax purposes of an investment as a Limited Partner.
FOR MEWBOURNE DEVELOPMENT CORPORATION USE ONLY
MEWBOURNE DEVELOPMENT CORPORATION
Managing General Partner
ACCEPTED: By:
----------------------------------
Title:
-------------------------------
Date:
--------------------------------
D-5
140
================================================================================
NO DEALER, SALESMAN OR ANY OTHER PERSON HAS BEEN AUTHORIZED TO GIVE ANY
INFORMATION OR TO MAKE ANY REPRESENTATIONS NOT CONTAINED IN THIS PROSPECTUS AND,
IF GIVEN OR MADE, SUCH INFORMATION OR REPRESENTATION MUST NOT BE RELIED UPON AS
HAVING BEEN AUTHORIZED. THIS PROSPECTUS DOES NOT CONSTITUTE AN OFFER TO BUY ANY
OF THE SECURITIES OFFERED HEREBY IN ANY JURISDICTION TO ANY PERSON TO WHOM IT IS
UNLAWFUL TO MAKE SUCH OFFER IN SUCH JURISDICTION.
----------
TABLE OF CONTENTS
Page
----
SUMMARY OF OFFERING.........................................................1
RISK FACTORS................................................................4
APPLICATION OF PROCEEDS....................................................15
PARTICIPATION IN COSTS AND REVENUES........................................18
COMPENSATION AND REIMBURSEMENT.............................................20
ESTIMATED DRILLING PROGRAM EXPENSES........................................22
DEFINITIONS................................................................23
TERMS OF THE OFFERING......................................................26
ADDITIONAL FINANCING.......................................................34
PLAN OF DISTRIBUTION.......................................................35
INVESTMENT OBJECTIVES......................................................36
PROPOSED ACTIVITIES........................................................36
MANAGEMENT.................................................................47
OWNERSHIP STRUCTURE OF MEWBOURNE COMPANIES.................................48
CONFLICTS OF INTEREST......................................................53
PRIOR ACTIVITIES...........................................................59
TAX ASPECTS................................................................72
COMPETITION, MARKETS AND REGULATION........................................91
LIABILITY OF GENERAL AND LIMITED PARTNERS..................................93
SUMMARY OF PARTNERSHIP AGREEMENT AND DRILLING PROGRAM AGREEMENT............95
LEGAL OPINIONS............................................................105
EXPERTS .................................................................105
WHERE YOU CAN FIND MORE INFORMATION.......................................105
INDEX TO FINANCIAL STATEMENTS.............................................106
Exhibit A: Form of Agreement of Partnership
Exhibit B: Form of Drilling Program Agreement
Exhibit C: Form of Special Subscription Instructions
Exhibit D: Form of Subscription Agreement
UNTIL 90 DAYS AFTER THE DATE OF THIS PROSPECTUS, AS AMENDED OR
SUPPLEMENTED, ALL DEALERS EFFECTING TRANSACTIONS IN THESE SECURITIES, WHETHER OR
NOT PARTICIPATING IN THIS DISTRIBUTION, MAY BE REQUIRED TO DELIVER A PROSPECTUS
WHEN ACTING AS UNDERWRITERS AND WITH RESPECT TO THEIR UNSOLD ALLOTMENTS OR
SUBSCRIPTIONS.
================================================================================
================================================================================
MEWBOURNE
ENERGY 99-00
DRILLING PROGRAMS
(PER PARTNERSHIP MINIMUM OFFERING AMOUNT)
1,000 LIMITED PARTNER INTERESTS
AT $1,000 PER INTEREST
MINIMUM PURCHASE OF
FIVE LIMITED PARTNER INTERESTS
1,000 GENERAL PARTNER INTERESTS
AT $1,000 PER INTEREST
MINIMUM PURCHASE OF
FIVE GENERAL PARTNER INTERESTS
------------------
PROSPECTUS
------------------
____________, 2000
================================================================================
141
PART II
INFORMATION NOT REQUIRED IN PROSPECTUS
All capitalized terms used and not defined in Part II of this Registration
Statement shall have the meanings assigned to them in the prospectus which forms
a part of this Registration Statement or the exhibits thereto.
ITEM 13. OTHER EXPENSES OF ISSUANCE AND DISTRIBUTION
Set forth below is an itemization of the estimated costs which will be
incurred in connection with the sale of the securities registered hereby if
4,000 Limited Partner Interests and 16,000 General Partner Interests are sold.
Costs of Offering:
Securities Act of 1933 Registration Fee ................................... $ 5,560
National Association of Securities Dealers, Inc. Filing Fee ............... 2,500
Blue Sky Qualification Fees and Expenses .................................. 26,000*
Printing .................................................................. 75,000*
Legal Fees and Expenses ................................................... 200,000*
Accounting Fees and Expenses .............................................. 10,000*
Expenses of Mewbourne Development Corporation Incurred in Connection
With the Distribution .................................................... 100,000*
Miscellaneous ............................................................. 50,000*
Total ..................................................................... $469,060
========
* Estimated
- ------------
ITEM 14. INDEMNIFICATION OF DIRECTORS AND OFFICERS
Section 5.4 of the partnership agreement provide that neither Mewbourne
Development Corporation nor any of its affiliate shall have any liability to a
partnership or to any partner thereof for any loss suffered by the partnership
that arises out of any action or inaction performed or omitted by Mewbourne
Development Corporation or such affiliate, unless the managing partner in good
faith has determined that such course of conduct or omission was not intended to
further the best interest of the partnership or that such course of conduct
constituted negligence or misconduct on the part of Mewbourne Development
Corporation or such affiliate. Section 6(f) of the drilling program agreements
provides parallel protection from liability to Mewbourne Oil Company, in its
individual capacity as the program manager, and affiliates of the program
manager.
Section 5.5 of the partnership agreements and Section 6(f) of the drilling
program agreements provides, subject to various conditions, for indemnification
of Mewbourne Development Corporation and its affiliates, and each permit,
subject to certain conditions, for insurance to be purchased and maintained on
behalf of Mewbourne Development Corporation and its affiliates against any
liabilities asserted against or expenses incurred by Mewbourne Development
Corporation and its affiliates in connection with activities of a partnership or
drilling program, as the case may be.
Section 17-108 of the Delaware Act provides that a Delaware limited
partnership may indemnify and hold harmless any partner or other person from and
against any and all claims and demands whatsoever.
Section 9 of the soliciting dealer agreements provide that the partnerships
and Mewbourne Development Corporation have agreed to indemnify the soliciting
dealers against certain liabilities, including certain liabilities under the
Securities Act of 1933. In addition, Mewbourne Development Corporation may enter
into similar agreements with
II-1
142
certain soliciting dealers on behalf of the partnerships under which Mewbourne
Development Corporation and the partnerships will indemnify those soliciting
dealers against certain liabilities, including certain liabilities under the
Securities Act of 1933.
As permitted by Section 102(b)(7) of the Delaware General Corporation Law,
Article 10 of each of Mewbourne Development Corporation's and Mewbourne Oil
Company's Certification of Incorporation contains a limitation of liability
provision under which a director will not be personally liable to Mewbourne
Development Corporation, Mewbourne Oil Company or their respective stockholders
for monetary damages resulting from breaches of his fiduciary duty of care as a
director, subject to certain limitations.
Article 7, Section 7 of each of Mewbourne Development Corporation's and
Mewbourne Oil Company's By- laws provides that Mewbourne Development Corporation
or Mewbourne Oil Company, as the case may be, shall indemnify its officer or
director to the fullest extent permitted under the Delaware General Corporation
Law. Section 145 thereof permits indemnification of an officer or director upon
a determination that such officer or director has met the applicable standard of
conduct. Under Section 145, such officer or director is required to have acted
in good faith and in a manner he reasonably believed to be in or not opposed to
the best interests of Mewbourne Development Corporation and, with respect to any
criminal action, without reasonable cause to believe his conduct was unlawful.
Section 145 does not authorize indemnification, in actions brought by or in the
right of a corporation, against judgments, fines or amounts paid in settlement,
nor does it provide for indemnification of expenses incurred in the defense or
settlement of claims as to which a director or officer is adjudged to be liable
to Mewbourne Development Corporation or Mewbourne Oil Company, as the case may
be, unless specifically authorized by the Delaware Court of Chancery or the
court in which such action is brought.
The above discussion of the provisions of Section 5.5 of the Partnership
Agreement, Section 6(f) of the drilling program agreement, Section 17-108 of the
Delaware Act, Sections 102(b)(7) and 145 of the Delaware General Corporation
Law, Article 10 of each of Mewbourne Development Corporation's and Mewbourne Oil
Company's Certificate of Incorporation, Article 7, Section 7 of each of
Mewbourne Development Corporation's and Mewbourne Oil Company's By-laws, and the
soliciting dealer agreements is not intended to be exhaustive and is
respectively qualified in its entirety by the applicable provisions of the
partnership agreements and drilling program agreements, the forms of which are
included as Exhibits A and B to the Prospectus forming a part of this
Registration Statement and are hereby incorporated herein by reference, the
Delaware Act and the Delaware General Corporation Law, Article 10 of each of
Mewbourne Development Corporation's and Mewbourne Oil Company's Certificate of
Incorporation , which are included as Exhibits 3.3 and 3.5, respectively, to
this Registration Statement and hereby incorporated herein by reference, Article
7, Section 7 of each of Mewbourne Development Corporation's and Mewbourne Oil
Company's By- laws, which are included as Exhibits 3.4 and 3.6, respectively, to
this Registration Statement and hereby are incorporated herein by reference, and
by the soliciting dealer agreements, the form of which is set forth as Exhibit
1.1 to the Registration Statement and is hereby incorporated herein by
reference.
ITEM 15. RECENT SALES OF UNREGISTERED SECURITIES
In connection with the formation of a partnership, the organizational
partner of such partnership will contribute $100 to the partnership's capital.
Upon the initial admission of general and limited partners to that partnership,
the subscription of the organizational partner in the partnership will be
terminated and the $100 contribution will be returned to him. The partnerships
have not otherwise sold or issued within the past three years any securities
which were not registered under the Securities Act of 1933.
II-2
143
ITEM 16. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
EXHIBIT
NUMBER EXHIBIT
- ------- -------
1.1 -- Form of Soliciting Dealer Agreement to be entered into between
Mewbourne Development Corporation and the Soliciting Dealers.+
1.2 -- Form of Dealer Manager Agreement.+
3.1 -- Certificate of Limited Partnership of Mewbourne Energy Partners
99-A, L.P.+
3.2 -- Form of Amendment to Certificate of Limited Partnership of
Mewbourne Energy Partners 99-A, L.P.+
3.3 -- Certificate of Incorporation of Mewbourne Development
Corporation.+
3.4 -- Bylaws of Mewbourne Development Corporation.+
3.5 -- Certificate of Incorporation of Mewbourne Oil Company.+
3.6 -- Bylaws of Mewbourne Oil Company.+
3.7 -- Form of Amendment to Certificate of Limited Partnership of
Mewbourne Energy Partners 00-A, L.P.+
4.1 -- Form of Agreement of Partnership of Mewbourne Energy Partners
99-A, L.P.+
4.2 -- Form of Subscription Agreement (filed as Exhibit D to the
Prospectus forming a part of this Registration Statement).*
4.3 -- Form of Special Subscription Instructions (filed as Exhibit C to
the Prospectus forming a part of this Registration Statement).*
4.4 -- Form of Certificate of Limited Partner Interest.+
4.5 -- Form of Certificate of General Partner Interest.+
4.6 -- Form of Agreement of Partnership of Mewbourne Energy Partners
00-A, L.P. (filed as Exhibit A to the Prospectus forming a part
of this Registration Statement).+
5.1 -- Opinion of Vinson & Elkins L.L.P., as to the legality of the
securities registered hereby.+
8.1 -- Opinion of Vinson & Elkins L.L.P., as to certain tax matters
arising in connection with the securities registered hereby.+
10.1 -- Form of Drilling Program Agreement among Mewbourne Development
Corporation, Mewbourne Oil Company and Mewbourne Energy Partners
99-A, L.P.+
10.2 -- Form of Escrow Agreement between Mewbourne Development
Corporation and Bank of America Texas, N.A.+
10.3 -- Form of Operating Agreement between Mewbourne Energy Partners -A,
L.P., Mewbourne Development Corporation and Mewbourne Oil
Company.+
II-3
144
EXHIBIT
NUMBER EXHIBIT
- ------- -------
10.4 -- Form of Drilling Program Agreement among Mewbourne Development
Corporation, Mewbourne Oil Company and Mewbourne Energy Partners
00-A, L.P. (filed as Exhibit B to the Prospectus forming part A
of this Registration Statement).+
23.1 -- Consent dated July 28, 1999 of PricewaterhouseCoopers LLP,
independent accountants.+
23.2 -- Consent of Vinson & Elkins L.L.P. (included as part of Exhibits
23.4).+
23.3 -- Consent dated July 28, 1999 of Forrest A. Garb & Associates,
Inc., independent engineers.+
23.4 -- Consent of Vinson & Elkins L.L.P. +
23.5 -- Consent dated March 8, 2000 of PricewaterhouseCoopers LLP,
independent accountants.+
23.6 -- Consent dated March 6, 2000 of Garb Grubbs Harris & Associates,
Inc., independent engineers.+
23.7 -- Consent of Vinson & Elkins L.L.P. dated March 8, 2000.+
23.8 -- Consent dated April 20, 2000 of PricewaterhouseCoopers LLP,
independent accountants.*
23.9 -- Consent dated April 19, 2000 of Garb Grubbs Harris & Associates,
Inc., independent engineers.*
23.10 -- Consent of Vinson & Elkins L.L.P. dated April 19, 2000.*
24.1 -- Power of Attorney (included on the signature page to the
Registration Statement).*
27.1 -- Financial Data Schedule.+
- ----------------
+Previously filed
*Filed herewith
ITEM 17. UNDERTAKINGS
The undersigned Registrant hereby undertakes as follows:
(1) to file, during any period in which offers or sales are being made, a
post-effective amendment to this Registration Statement: (i) to include any
prospectus required by Section 10(a)(3) of the Securities Act; (ii) to reflect
in the prospectus any facts or events arising after the effective date of the
Registration Statement (or the most recent post-effective amendment thereof)
which, individually or in the aggregate, represent a fundamental change in the
information set forth in the Registration Statement; and (iii) to include any
material information with respect to the plan of distribution not previously
disclosed in the Registration Statement or any material change to such
information in the Registration Statement; provided, however, that subparagraphs
(1)(i) and (1)(ii) above do not apply if the Registration Statement is on Form
S-3 or Form S-8, and the information required to be included in a post-effective
amendment by those paragraphs is contained in periodic reports filed by the
Registrant pursuant to section 13 or section 15(d) of the Securities Exchange
Act of 1934 that are incorporated by reference in the Registration Statement.
II-4
145
(2) that, for the purpose of determining any liability under the Securities
Act, each such post-effective amendment shall be deemed to be a new registration
statement relating to the securities offered therein, and the offering of such
securities at that time shall be deemed to be the initial bona fide offering
thereof.
(3) that all post-effective amendments will comply with the applicable
forms, rules and regulations of the Securities and Exchange Commission in effect
at the time such post-effective amendments are filed.
(4) to remove from registration by means of a post-effective amendment any
of the securities being registered which remain unsold at the termination of the
offering.
(5) to not identify to any third party any prospects that will be, or are
likely to be, purchased by a partnership with the proceeds from the sale of the
securities offered hereby or are representative of prospects which may be
purchased by the partnership with the proceeds from the sale of the securities
offered hereby, whether such third party is a soliciting dealer or other party
involved in making or directing investment decisions regarding the purchase of
the securities offered hereby, except to the extent such prospects have been
identified in the prospectus or an amendment thereto.
To the extent a review of prospects or lease inventory is permitted to
third parties:
(a) it will be incidental to a soliciting dealer's due diligence
examination;
(b) no reference to any specific prospect, unless such prospect is
described in the prospectus or an amendment to the prospectus, will appear
in any analysis or report on the securities offered hereby prepared by such
third party; and
(c) any third party, prior to receiving permission to examine
prospects, will agree to the above conditions, and the Registrant will file
a copy of such agreement(s) as an exhibit to the Registration Statement.
No prospective investors or their representative will be permitted to
examine any prospects or inventory or data related thereto that are not
described or set forth in the prospectus or an amendment to the prospectus.
(6) to provide to the partners of a partnership the financial statements
required by Form 10-K for the first full fiscal year of operations of the
partnership.
(7) to send to each purchaser of the securities offered hereby, on at least
an annual basis, a detailed statement of any transactions by the Partnership to
which that purchaser has been admitted as a partner with the Managing Partner or
its affiliates and fees, commissions, compensation, and other benefits paid or
accrued to the Managing Partner or its affiliates for the fiscal year completed,
showing the amount paid or accrued to each recipient and the services performed.
(8) to file a sticker supplement pursuant to Rule 424(c) under the
Securities Act of 1933 during the distribution period for the partnerships
describing each property not identified in the Prospectus at such time as there
arises a reasonable probability that such property will be acquired by such
Partnership and to consolidate all such stickers into a post-effective amendment
filed at least once every three months, with the information contained in such
amendment provided simultaneously to any existing general and limited partners
of such partnership. Each sticker supplement should disclose all compensation
and fees received by the Managing Partner and its affiliates in connection with
any such acquisition. The post-effective amendment shall include audited
financial statements meeting the requirements of Rule 3-05 of Regulation S-X
only for properties acquired during such distribution period.
(9) to file, after the end of the end of the distribution period, a current
report on Form 8-K containing the financial statements and any additional
information required by Rule 3-05 of Regulation S-X as such is required under
II-5
146
Item 7 of Form 8-K, to reflect each commitment (i.e., the signing of a binding
purchase agreement) made after the end of the distribution period involving the
use of 10% or more (on a cumulative basis) of the net proceeds of the offering
and to provide the information contained in such report to the limited partners
at least once each quarter after the distribution period of the offering has
ended.
Insofar as indemnification for liabilities arising under the Securities Act
of 1933 may be permitted to directors, officers and controlling persons of
Mewbourne Development Corporation pursuant to the foregoing provisions, or
otherwise, Mewbourne Development Corporation has been advised that in the
opinion of the Securities and Exchange Commission such indemnification is
against public policy as expressed in the Securities Act of 1933 and is,
therefore, unenforceable. In the event that a claim for indemnification against
such liabilities (other than the payment by Mewbourne Development Corporation of
expenses incurred or paid by a director, officer or person controlling Mewbourne
Development Corporation in the successful defense of any action, suit or
proceeding) is asserted by such director, officer or controlling person in
connection with the securities being registered, Mewbourne Development
Corporation will, unless in the opinion of its counsel the matter has been
settled by controlling precedent, submit to a court of appropriate jurisdiction
the question whether such indemnification by it is against public policy as
expressed in the Securities Act of 1933 and will be governed by the final
adjudication of such issue.
II-6
147
SIGNATURES
Pursuant to the requirements of the Securities Act of 1933, the Registrant
has duly caused this Registration Statement to be signed on its behalf by the
undersigned, thereunto duly authorized, in the city of Tyler, State of Texas, on
April 21, 2000.
MEWBOURNE ENERGY 99-00 DRILLING PROGRAMS,
consisting of Mewbourne Energy Partners 99-A, L.P., a
Delaware limited partnership and Mewbourne Energy Partners
00-A, L.P., a Delaware limited partnership
By: MEWBOURNE DEVELOPMENT CORPORATION,
Managing Partner
By: /s/ Curtis W. Mewbourne
---------------------------------------------------
CURTIS W. MEWBOURNE,
President and Director
Pursuant to the requirements of the Securities Act of 1933, this
Registration Statement has been signed by the following persons in the
capacities and on the dates indicated. Each person whose signature appears below
hereby authorizes and appoints J. Roe Buckley as their attorney-in-fact to sign
on their behalf individually and in the capacity stated below all amendments and
post-effective amendments to this Registration Statement as such
attorney-in-fact may deem necessary or appropriate.
Signature Title Date
--------- ----- ----
* President and Director April 21, 2000
- ------------------------ (Principal Executive Officer)
CURTIS W. MEWBOURNE
* Treasurer April 21, 2000
- ------------------------ (Principal Financial and
J. ROE BUCKLEY Accounting Officer)
* Director April 21, 2000
- ------------------------
DOROTHY M. CUENOD
* Director April 21, 2000
- ------------------------
RUTH M. BUCKLEY
* Director April 21, 2000
- ------------------------
JULIE M. GREENE
*By: /s/ J. Roe Buckley
--------------------
J. Roe Buckley
Attorney-in-Fact
II-7
148
EXHIBIT INDEX
-------------
EXHIBIT
NUMBER EXHIBIT
- ------- -------
1.1 -- Form of Soliciting Dealer Agreement to be entered into between
Mewbourne Development Corporation and the Soliciting Dealers.+
1.2 -- Form of Dealer Manager Agreement.+
3.1 -- Certificate of Limited Partnership of Mewbourne Energy Partners
99-A, L.P.+
3.2 -- Form of Amendment to Certificate of Limited Partnership of
Mewbourne Energy Partners 99-A, L.P.+
3.3 -- Certificate of Incorporation of Mewbourne Development
Corporation.+
3.4 -- Bylaws of Mewbourne Development Corporation.+
3.5 -- Certificate of Incorporation of Mewbourne Oil Company.+
3.6 -- Bylaws of Mewbourne Oil Company.+
3.7 -- Form of Amendment to Certificate of Limited Partnership of
Mewbourne Energy Partners 00-A, L.P.+
4.1 -- Form of Agreement of Partnership of Mewbourne Energy Partners
99-A, L.P.+
4.2 -- Form of Subscription Agreement (filed as Exhibit D to the
Prospectus forming a part of this Registration Statement).*
4.3 -- Form of Special Subscription Instructions (filed as Exhibit C to
the Prospectus forming a part of this Registration Statement).*
4.4 -- Form of Certificate of Limited Partner Interest.+
4.5 -- Form of Certificate of General Partner Interest.+
4.6 -- Form of Agreement of Partnership of Mewbourne Energy Partners
00-A, L.P. (filed as Exhibit A to the Prospectus forming a part
of this Registration Statement).+
5.1 -- Opinion of Vinson & Elkins L.L.P., as to the legality of the
securities registered hereby.+
8.1 -- Opinion of Vinson & Elkins L.L.P., as to certain tax matters
arising in connection with the securities registered hereby.+
10.1 -- Form of Drilling Program Agreement among Mewbourne Development
Corporation, Mewbourne Oil Company and Mewbourne Energy Partners
99-A, L.P.+
10.2 -- Form of Escrow Agreement between Mewbourne Development
Corporation and Bank of America Texas, N.A.+
10.3 -- Form of Operating Agreement between Mewbourne Energy Partners -A,
L.P., Mewbourne Development Corporation and Mewbourne Oil
Company.+
149
EXHIBIT
NUMBER EXHIBIT
- ------- -------
10.4 -- Form of Drilling Program Agreement among Mewbourne Development
Corporation, Mewbourne Oil Company and Mewbourne Energy Partners
00-A, L.P. (filed as Exhibit B to the Prospectus forming part A
of this Registration Statement).+
23.1 -- Consent dated July 28, 1999 of PricewaterhouseCoopers LLP,
independent accountants.+
23.2 -- Consent of Vinson & Elkins L.L.P. (included as part of Exhibits
23.4).+
23.3 -- Consent dated July 28, 1999 of Forrest A. Garb & Associates,
Inc., independent engineers.+
23.4 -- Consent of Vinson & Elkins L.L.P. +
23.5 -- Consent dated March 8, 2000 of PricewaterhouseCoopers LLP,
independent accountants.+
23.6 -- Consent dated March 6, 2000 of Garb Grubbs Harris & Associates,
Inc., independent engineers.+
23.7 -- Consent of Vinson & Elkins L.L.P. dated March 8, 2000.+
23.8 -- Consent dated April 20, 2000 of PricewaterhouseCoopers LLP,
independent accountants.*
23.9 -- Consent dated April 19, 2000 of Garb Grubbs Harris & Associates,
Inc., independent engineers.*
23.10 -- Consent of Vinson & Elkins L.L.P. dated April 19, 2000.*
24.1 -- Power of Attorney (included on the signature page to the
Registration Statement).*
27.1 -- Financial Data Schedule.+
- ----------------
+Previously filed
*Filed herewith