Unit 2011 Employee Oil and Gas Limited Partnership Agreement



 Exhibit 10.2.33 

CONFIDENTIAL 
 For Private
Placement Purposes Only 
 UNIT 2011 EMPLOYEE OIL AND GAS LIMITED PARTNERSHIP 

7130 South Lewis Avenue, Suite 1000 
 Tulsa, Oklahoma 74136 
 (918) 493-7700 

A PRIVATE OFFERING 
 OF 
 UNITS OF LIMITED PARTNERSHIP INTEREST 

 
  

THESE SECURITIES HAVE NOT BEEN REGISTERED UNDER THE SECURITIES ACT OF 1933, AS AMENDED, OR UNDER APPLICABLE STATE SECURITIES ACTS IN
RELIANCE ON EXEMPTIONS PROVIDED BY SUCH ACTS. THESE SECURITIES MAY NOT BE SOLD OR TRANSFERRED IN THE ABSENCE OF AN EFFECTIVE REGISTRATION UNDER SUCH ACTS OR AN OPINION OF COUNSEL ACCEPTABLE TO THE GENERAL PARTNER THAT SUCH REGISTRATION IS NOT
REQUIRED. FURTHER, THE RESALE OF A UNIT MAY RESULT IN SUBSTANTIAL TAX LIABILITY TO THE INVESTOR. SEE “FEDERAL INCOME TAX CONSIDERATIONS.” ACCORDINGLY, THESE UNITS SHOULD BE CONSIDERED ONLY FOR LONG-TERM INVESTMENT. SEE “PLAN OF
DISTRIBUTION — SUITABILITY OF INVESTORS.” 
  

 
 THE
INFORMATION CONTAINED IN THIS PRIVATE OFFERING MEMORANDUM IS PROVIDED BY THE GENERAL PARTNER SOLELY FOR THE PERSONS RECEIVING IT FROM THE GENERAL PARTNER AND ANY REPRODUCTION OR DISTRIBUTION OF THIS PRIVATE OFFERING MEMORANDUM, IN WHOLE OR IN PART,
OR THE DIVULGENCE OF ANY OF ITS CONTENTS IS PROHIBITED AND MAY CONSTITUTE A VIOLATION OF CERTAIN STATE SECURITIES LAWS. THE OFFEREE, BY ACCEPTING DELIVERY OF THIS PRIVATE OFFERING MEMORANDUM, AGREES TO RETURN IT AND ALL ENCLOSED DOCUMENTS TO THE
GENERAL PARTNER IF THE OFFEREE DOES NOT UNDERTAKE TO PURCHASE ANY OF THE UNITS OFFERED HEREBY. 
  

 
 Private Offering
Memorandum Date December 30, 2010. 







 900 Preformation 

Units of Limited Partnership Interest 
 in the 
 UNIT 2011 EMPLOYEE 

OIL AND GAS LIMITED PARTNERSHIP 
  

 
 $1,000 Per Unit
Plus Possible 
 Additional Assessments of $100 Per Unit 
 (Minimum Investment - 2 Units) 
 Minimum Aggregate Subscriptions Necessary

 to Form Partnership - 50 Units 
  

 
 A maximum of
900 (minimum of 50) units of limited partnership interest (“Units”) in the UNIT 2011 EMPLOYEE OIL AND GAS LIMITED PARTNERSHIP, a proposed Oklahoma limited partnership (the “Partnership”), are being offered privately only to
certain employees of Unit Corporation (“UNIT”) and its subsidiaries and the directors of UNIT at a price of $1,000 per Unit. Subscriptions shall be for not less than 2 Units ($2,000). The Partnership is being formed for the purpose of
conducting oil and gas drilling and development operations. Purchasers of the Units will become Limited Partners in the Partnership. Unit Petroleum Company (“UPC” or the “General Partner”) will serve as General Partner of the
Partnership. UPC’s address is 7130 South Lewis Avenue, Suite 1000, Tulsa, Oklahoma 74136, and telephone (918) 493-7700. 
 THE RIGHTS AND OBLIGATIONS OF THE GENERAL PARTNER 
 AND THE LIMITED
PARTNERS ARE GOVERNED BY THE 
 AGREEMENT OF LIMITED PARTNERSHIP (THE “AGREEMENT”), 

A COPY OF WHICH ACCOMPANIES THIS MEMORANDUM AND IS 
 INCORPORATED HEREIN BY REFERENCE 
 AN INVESTMENT IN THE UNITS IS
SPECULATIVE AND INVOLVES 
 A HIGH DEGREE OF RISK. SEE “RISK FACTORS.” CERTAIN 

SIGNIFICANT RISKS INCLUDE: 
  

	 	•	 	 Drilling to establish productive oil and natural gas properties is inherently speculative. 



 

	 	•	 	 Participants will rely solely on the management capability and expertise of the General Partner. 



 

	 	•	 	 Limited Partners must assume the risks of an illiquid investment. 



 

	 	•	 	 Investment in the Units is suitable only for investors having sufficient financial resources and who desire a long-term investment.



  

	 	•	 	 Conflicts of interest exist and additional conflicts of interest may arise between the General Partner and the Limited Partners, and there are no
pre-determined procedures for resolving any such conflicts. 


  

	 	•	 	 Significant tax considerations to be considered by an investor include: 



 

	 	•	 	 possible audit of income tax returns of the Partnership and/or the Limited Partners and adjustment to their reported tax liabilities;



  

	 	•	 	 a Limited Partner will not benefit from his or her share of Partnership deductions in excess of his or her share of Partnership income unless he or
she has passive income from other activities; 



  
 ii 










	 	•	 	 the amount of any cash distribution which a Limited Partner may receive from the Partnership could be insufficient to pay the tax liability incurred
by such Limited Partner with respect to income or gain allocated to such Limited Partner by the Partnership; and 


  

	 	•	 	 the possibility that some or all of the oil and gas tax provisions in the Obama administration’s FY 2011 budget proposal will be enacted.



  

	 	•	 	 There can be no assurance that the Partnership will have adequate funds to provide cash distributions to the Limited Partners. The amount and timing
of any such distributions will be within the complete discretion of the General Partner. 


  

	 	•	 	 Certain provisions in the Agreement modify what would otherwise be the applicable Oklahoma law as to the fiduciary standards for general partners in
limited partnerships. Those standards in the Agreement could be less advantageous to the Limited Partners than the corresponding fiduciary standards otherwise applicable under Oklahoma law. The purchase of Units may be deemed as consent to the
fiduciary standards set forth in the Agreement. 


  

 
 EXCEPT AS
STATED UNDER “ADDITIONAL INFORMATION,” NO PERSON HAS BEEN AUTHORIZED TO GIVE ANY INFORMATION OR TO MAKE ANY REPRESENTATIONS OTHER THAN THOSE CONTAINED IN THIS PRIVATE OFFERING MEMORANDUM IN CONNECTION WITH THIS OFFERING AND SUCH
REPRESENTATIONS, IF ANY, MAY NOT BE RELIED ON. THE INFORMATION CONTAINED IN THIS PRIVATE OFFERING MEMORANDUM IS AS OF THE DATE OF THIS MEMORANDUM UNLESS ANOTHER DATE IS SPECIFIED. 

 
  

PROSPECTIVE INVESTORS ARE NOT TO CONSTRUE THE CONTENTS OF THIS PRIVATE OFFERING MEMORANDUM AS LEGAL, BUSINESS, OR TAX ADVICE. EACH
INVESTOR SHOULD CONSULT HIS OR HER OWN ATTORNEY, BUSINESS ADVISOR AND TAX ADVISOR AS TO LEGAL, BUSINESS, TAX AND RELATED MATTERS CONCERNING HIS OR HER INVESTMENT. PROSPECTIVE INVESTORS ARE URGED TO REQUEST ANY ADDITIONAL INFORMATION THEY MAY
CONSIDER NECESSARY TO MAKE AN INFORMED INVESTMENT DECISION. 
  

 
 THE
SECURITIES OFFERED BY THIS MEMORANDUM HAVE NOT BEEN APPROVED OR DISAPPROVED BY THE UNITED STATES SECURITIES AND EXCHANGE COMMISSION, THE OKLAHOMA SECURITIES COMMISSION OR BY THE SECURITIES REGULATORY AUTHORITY OF ANY OTHER STATE, NOR HAS ANY
COMMISSION OR AUTHORITY PASSED ON OR ENDORSED THE MERITS OF THIS OFFERING OR THE ACCURACY OR ADEQUACY OF THIS PRIVATE OFFERING MEMORANDUM. ANY REPRESENTATION CONTRARY TO THE FOREGOING IS UNLAWFUL. 

 
  

THESE UNITS ARE BEING OFFERED SUBJECT TO PRIOR SALE, TO WITHDRAWAL, CANCELLATION OR MODIFICATION OF THE OFFER WITHOUT NOTICE AND TO
THE FURTHER CONDITIONS SET FORTH HEREIN. 

  
 iii









 ADDITIONAL INFORMATION 

Each prospective investor, or his or her qualified representative named in writing, has the opportunity (1) to obtain additional
information necessary to verify the accuracy of the information supplied herewith or hereafter, and (2) to ask questions and receive answers concerning the terms and conditions of the offering. If you desire to avail yourself of the
opportunity, please contact: 
 Mark E. Schell 
 Senior Vice President and General Counsel 
 Unit Petroleum Company 

7130 South Lewis Avenue, Suite 1000 
 Tulsa, Oklahoma 74136 
 (918) 493-7700 

The following documents and instruments are available to qualified offerees on written request: 

 

	1.	Amended and Restated Certificate of Incorporation and By-Laws of UNIT. 

  

	2.	Certificate of Incorporation and By-Laws of Unit Petroleum Company. 

  

	3.	UNIT’s Employees’ Thrift Plan. 

  

	4.	Restated Unit Corporation Amended and Restated Stock Option Plan and related prospectuses covering shares of Common Stock issuable on exercise of outstanding options.


  

	5.	UNIT’s 2000 Non-Employee Directors’ Stock Option Plan, as amended and restated. 


 

	6.	UNIT’s Stock and Incentive Compensation Plan. 

  

	7.	The Credit Agreement and the notes payable of UNIT. 

  

	8.	All periodic reports on Forms 10-K, 10-Q and 8-K and all proxy materials filed by or on behalf of UNIT with the SEC under the Securities Exchange Act of 1934, as
amended, during calendar year 2010, the annual report to shareholders and all quarterly reports to shareholders submitted by UNIT to its shareholders during calendar year 2010. 


 

	9.	UNIT’s current Registration Statements on Form S-3 and all supplemental prospectuses filed with the SEC under Rule 424. 


 

	10.	The agreements of limited partnership for the prior oil and gas drilling programs and prior employee programs of UPC, UNIT and Unit Drilling and Exploration Company
(“UDEC”). 

  

	11.	All periodic reports filed with the SEC and all reports and information provided to limited partners in all limited partnerships of which UPC, UNIT or UDEC now serves
or has served in the past as a general partner. 

  

	12.	The agreement of limited partnership for the Unit 1986 Energy Income Limited Partnership. 


  
 iv 









 SUMMARY OF CONTENTS 

 

					
	 	  	Page	 
	 SUMMARY OF PROGRAM
	  	 	1	  
	 Terms of the Offering
	  	 	1	  
	 Risk Factors
	  	 	2	  
	 Additional Financing
	  	 	3	  
	 Proposed Activities
	  	 	4	  
	 Application of Proceeds
	  	 	4	  
	 Participation in Costs and Revenues
	  	 	5	  
	 Compensation
	  	 	5	  
	 Federal Income Tax Considerations; Opinion of Counsel
	  	 	5	  
	 RISK FACTORS
	  	 	6	  
	 INVESTMENT RISKS
	  	 	6	  
	 TAX STATUS AND TAX RISKS
	  	 	11	  
	 OPERATIONAL RISKS
	  	 	12	  
	 TERMS OF THE OFFERING
	  	 	14	  
	 General
	  	 	14	  
	 Limited Partnership Interests
	  	 	14	  
	 Subscription Rights
	  	 	14	  
	 Payment for Units; Delinquent Installment
	  	 	15	  
	 Right of Presentment
	  	 	16	  
	 Rollup or Consolidation of Partnership
	  	 	17	  
	 ADDITIONAL FINANCING
	  	 	18	  
	 Additional Assessments
	  	 	18	  
	 Prior Programs
	  	 	18	  
	 Partnership Borrowings
	  	 	18	  
	 PLAN OF DISTRIBUTION
	  	 	19	  
	 Suitability of Investors
	  	 	19	  
	 RELATIONSHIP OF THE PARTNERSHIP, THE GENERAL PARTNER AND AFFILIATES
	  	 	20	  
	 PROPOSED ACTIVITIES
	  	 	20	  
	 General
	  	 	20	  
	 Partnership Objectives
	  	 	22	  
	 Areas of Interest
	  	 	22	  
	 Transfer of Properties
	  	 	23	  
	 Record Title to Partnership Properties
	  	 	23	  
	 Marketing of Reserves
	  	 	23	  
	 Conduct of Operations
	  	 	23	  
	 APPLICATION OF PROCEEDS
	  	 	24	  
	 PARTICIPATION IN COSTS AND REVENUES
	  	 	24	  
	 COMPENSATION
	  	 	26	  
	 Supervision of Operations
	  	 	26	  
	 Purchase of Equipment and Provision of Services
	  	 	26	  
	 Prior Programs
	  	 	27	  
	 MANAGEMENT
	  	 	28	  
	 The General Partner
	  	 	28	  
	 Officers, Directors and Key Employees
	  	 	29	  
	 Prior Employee Programs
	  	 	31	  
	 Ownership of Common Stock
	  	 	32	  
	 Interest of Management in Certain Transactions
	  	 	33	  
	 CONFLICTS OF INTEREST
	  	 	33	  
	 Acquisition of Properties and Drilling Operations
	  	 	34	  
	 Participation in UNIT’s Drilling or Income Programs
	  	 	35	  
	 Transfer of Properties
	  	 	35	  
	 Partnership Assets
	  	 	35	  
	 Transactions with the General Partner or Affiliates
	  	 	36	  
	 Right of Presentment Price Determination
	  	 	36	  
	 Receipt of Compensation Regardless of Profitability
	  	 	36	  
	 Legal Counsel
	  	 	36	  
	 FIDUCIARY RESPONSIBILITY
	  	 	36	  
	 General
	  	 	36	  


  
 v 









					
	 Liability and Indemnification
	  	 	37	  
	 PRIOR ACTIVITIES
	  	 	38	  
	 Prior Employee Programs
	  	 	40	  
	 Results of the Prior Oil and Gas Programs
	  	 	41	  
	 FEDERAL INCOME TAX CONSIDERATIONS
	  	 	50	  
	 Summary of Conclusions
	  	 	51	  
	 General Tax Effects of Partnership Structure
	  	 	53	  
	 Ownership of Partnership Properties
	  	 	53	  
	 Intangible Drilling and Development Costs Deductions
	  	 	54	  
	 Depletion Deductions
	  	 	55	  
	 Production Activities Deduction
	  	 	55	  
	 Depreciation Deductions
	  	 	55	  
	 Transaction Fees
	  	 	55	  
	 Basis and At Risk Limitations
	  	 	56	  
	 Passive Loss Limitations
	  	 	56	  
	 Gain or Loss on Sale of Partnership Property
	  	 	57	  
	 Disposition of Units
	  	 	58	  
	 Partnership Distributions
	  	 	59	  
	 Partnership Allocations
	  	 	59	  
	 Administrative Matters
	  	 	59	  
	 Accounting Methods and Periods
	  	 	60	  
	 State and Local Taxes
	  	 	61	  
	 COMPETITION, MARKETS AND REGULATION
	  	 	61	  
	 Marketing of Production
	  	 	61	  
	 Regulation of Partnership Operations
	  	 	61	  
	 Natural Gas Price Regulation
	  	 	62	  
	 Oil Pipeline Regulation
	  	 	63	  
	 State Regulation of Oil and Gas Production
	  	 	63	  
	 Legislative and Regulatory Production and Pricing Proposals
	  	 	63	  
	 Production and Environmental Regulation
	  	 	64	  
	 SUMMARY OF THE LIMITED PARTNERSHIP AGREEMENT
	  	 	64	  
	 Partnership Distributions
	  	 	64	  
	 Deposit and Use of Funds
	  	 	65	  
	 Power and Authority
	  	 	65	  
	 Rollup or Consolidation of the Partnership
	  	 	66	  
	 Limited Liability
	  	 	66	  
	 Records, Reports and Returns
	  	 	66	  
	 Transferability of Interests
	  	 	67	  
	 Amendments
	  	 	68	  
	 Voting Rights
	  	 	68	  
	 Exculpation and Indemnification of the General Partner
	  	 	69	  
	 Termination
	  	 	69	  
	 Insurance
	  	 	70	  
	 COUNSEL
	  	 	70	  
	 GLOSSARY
	  	 	70	  
	 FINANCIAL STATEMENTS
	  	 	74	  
		
	 EXHIBIT A - AGREEMENT OF LIMITED PARTNERSHIP
	  	 	A-1	  
	 EXHIBIT B - LEGAL OPINION
	  	 	B-1	  


  
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 SUMMARY OF PROGRAM 
 This summary is not a complete description of the terms and consequences of an investment in the Partnership and is qualified in its entirety by the more detailed information appearing throughout this
Private Offering Memorandum (this “Memorandum”). For definitions of certain terms used in this Memorandum, see “GLOSSARY.” 

Terms of the Offering 
 Limited
Partnership Interests. Unit 2011 Employee Oil and Gas Limited Partnership, a proposed Oklahoma limited partnership (the “Partnership”), offers 900 preformation units of limited partnership interest (“Units”) in the
Partnership. The offer is made only to certain employees of Unit Corporation (“UNIT”) and its subsidiaries and directors of UNIT (see “TERMS OF THE OFFERING — Subscription Rights”). Unless the context otherwise requires, all
references in this Memorandum to UNIT shall include all or any of its subsidiaries. Unit Petroleum Company (“UPC” or the “General Partner”), a wholly owned subsidiary of UNIT, will serve as General Partner of the Partnership.

 To invest in the Units, the Limited Partner Subscription Agreement and Suitability Statement (the “Subscription Agreement”) (see
Attachment I to Exhibit A to this Memorandum) must be signed and forwarded to the offices of the General Partner at its address listed on the cover of this Memorandum. The Subscription Agreement must be received by the General Partner not later than
5:00 P.M. Central Standard Time on January 21, 2011 (extendable by the General Partner for up to 30 days). Subscription Agreements may be delivered to the office of the General Partner. No payment is required on delivery of the Subscription
Agreement. Payment for the Units will be made either (i) in four equal Installments, the first Installment being due on March 15, 2011 and the remaining three Installments being due on June 15, September 15, and
December 15, 2011, respectively, or (ii) through equal deductions from 2011 salary commencing immediately after formation of the Partnership. 
 The purchase price of each Unit is $1,000, and the minimum permissible purchase is two Units ($2,000) for each subscriber. Additional Assessments of up to $100 per Unit may be required (see
“ADDITIONAL FINANCING — Additional Assessments”). Maximum purchases by employees (other than directors) will be for an amount equal to one-half of their base salaries for calendar year 2010; provided, however, that the General Partner
may, at its discretion, accept subscriptions for greater amounts. Each member of the Board of Directors of UNIT may subscribe for up to 300 Units ($300,000). The Partnership must sell at least 50 Units ($50,000) before the Partnership will be
formed. No Units will be offered for sale after the Effective Date (see “GLOSSARY”) except in compliance with the provisions of Article XIII of the Agreement. The General Partner may, at its option, purchase Units as a Limited Partner,
including any amount that may be necessary to meet the minimum number of Units required for formation of the Partnership. The Partnership will terminate on December 31, 2041, unless it is terminated earlier under the provisions of the Agreement
or by operation of law. See “TERMS OF THE OFFERING — Limited Partnership Interests”; “TERMS OF THE OFFERING — Subscription Rights”; and “SUMMARY OF THE LIMITED PARTNERSHIP AGREEMENT — Termination.”

 The offering will be made privately by the officers and directors of UPC or UNIT, except that in states which require participation by a
registered broker-dealer in the offer and sale of securities, the Units will be offered through such broker-dealer as may be selected by the General Partner. Any participating broker-dealer may be reimbursed for actual out-of-pocket expenses. Such
reimbursements will be borne by the General Partner. 
 Subscription Rights. Only certain salaried employees of UNIT or any of its
subsidiaries whose annual base salaries for 2010 have been set at $60,000 or more and directors of UNIT are eligible to subscribe for Units. Employees may not purchase Units for an amount in excess of one-half of their base salaries for calendar
year 2010; provided, however, that the General Partner may, at its discretion, accept a subscription for a greater amount. Directors’ subscriptions may not be for more than 300 Units ($300,000). Only employees and directors who are U.S.
citizens are eligible to participate in the offering. In addition, employees and directors must be able to bear the economic risks of an investment in the Partnership and must have sufficient investment experience and expertise to evaluate the risks
and merits of such an investment. See “TERMS OF THE OFFERING — Subscription Rights.” 

  
 1 








 Right of Presentment. After December 31, 2011, the Limited Partners will have the right
to present their Units to the General Partner for purchase. The General Partner will not be obligated to purchase more than 20% of the then outstanding Units in any one calendar year. The purchase price to be paid for the Units will be determined by
a specific valuation formula. See “TERMS OF THE OFFERING — Right of Presentment” for a description of the valuation formula and a discussion of the manner in which the right of presentment may be exercised by the Limited Partners.

 Risk Factors 
 An
investment in the Partnership has many risks. The “RISK FACTORS” section of this Memorandum contains a detailed discussion of the most important risks, organized into Investment Risks (the risks related to the Partnership’s investment
in oil and gas properties and drilling activities, to an investment in the Partnership and to the provisions of the Agreement); Tax Risks (the risks arising from the tax laws as they apply to the Partnership and its investment in oil and gas
properties and drilling activities); and Operational Risks (the risks involved in conducting oil and gas operations). The following are certain of the risks which are more fully described under “RISK FACTORS”. Each prospective investor
should review the “RISK FACTORS” section carefully before deciding to subscribe for Units. 
 Investment Risks: 

 

	 	•	 	 Oil and gas prices have remained relatively lower than in the past during recent months due to the continued slow national and global economic
environment. A continued slowdown in the national and global economy will also result (to varying degrees) in a reduction in the demand for oil and gas products. Significant reductions in demand for oil and gas would result in lower prices for our
products and force us to curtail our production of those products which, in turn, would affect our financial results. 


  

	 	•	 	 Future oil and natural gas prices are unpredictable. Partnership distributions, if any, to the Limited Partners will be adversely affected by declines
in oil and natural gas prices. 


  

	 	•	 	 The General Partner is authorized under the Agreement to cause, in its sole discretion, the sale or transfer of the Partnership’s assets to, or
the merger or consolidation of the Partnership with, another partnership, corporation or other business entity. Such action could have a material impact on the nature of the investment of all Limited Partners. 



 

	 	•	 	 Except for certain transfers to the General Partner and other restricted transfers, the Agreement prohibits a Limited Partner from transferring Units.
Thus, except for the limited right of the Limited Partners after December 31, 2011 to present their Units to the General Partner for purchase, Limited Partners will not be able to liquidate their investments. 



 

	 	•	 	 The Partnership could be formed with as little as $50,000 in Capital Contributions (excluding the Capital Contributions of the General Partner). As the
total amount of Capital Contributions to the Partnership will determine the number and diversification of Partnership Properties, the ability of the Partnership to pursue its investment objectives may be restricted in the event that the Partnership
receives only the minimum amount of Capital Contributions. 


  

	 	•	 	 The drilling and completion operations to be undertaken by the Partnership for the development of oil and natural gas reserves involve the possibility
of a total loss of an investment in the Partnership. 


  

	 	•	 	 The General Partner will have the exclusive management and control of all aspects of the business of the Partnership. The Limited Partners will have no
opportunity to participate in the management and control of any aspect of the Partnership’s activities. Accordingly, the Limited Partners will be entirely dependent on the management skills and expertise of the General Partner.



  

	 	•	 	 Conflicts of interest exist and additional conflicts of interest may arise between the General Partner and the Limited Partners, and there are no
pre-determined procedures for resolving any conflicts. Accordingly the General Partner could cause the Partnership to take actions to the benefit of the General Partner but not to the benefit of the Limited Partners. 



  
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	 	•	 	 Certain provisions in the Agreement modify what would otherwise be the applicable Oklahoma law as to the fiduciary standards for a general partner in a
limited partnership. The fiduciary standards in the Agreement could be less advantageous to the Limited Partners and more advantageous to the General Partner than corresponding fiduciary standards otherwise applicable under Oklahoma law. The
purchase of Units may be deemed as consent to the fiduciary standards set forth in the Agreement. 


  

	 	•	 	 There can be no assurances that the Partnership will have adequate funds to provide cash distributions to the Limited Partners. The amount and timing
of any such distributions will be within the complete discretion of the General Partner. 


  

	 	•	 	 The amount of any cash distributions which Limited Partners may receive from the Partnership could be insufficient to pay the tax liability incurred by
such Limited Partners with respect to income or gain allocated to such Limited Partners by the Partnership. 


 Tax Risks:

  

	 	•	 	 Tax laws and regulations applicable to partnership investments may change at any time and these changes may be applied retroactively.



  

	 	•	 	 Certain allocations of income, gain, loss and deduction between the Partners may be challenged by the Internal Revenue Service (the
“Service”). A successful challenge would likely result in a Limited Partner having to report additional taxable income or being denied a deduction. 



 

	 	•	 	 It is anticipated that a Limited Partner will be allocated deductions in excess of his or share of Partnership income for the first year(s) of the
Partnership. Unless a Limited Partner has substantial current taxable income from trade or business activities in which the Limited Partner does not materially participate, his or her use of deductions allocated from the Partnership may be limited.



  

	 	•	 	 Federal income tax payable by a Limited Partner by reason of his or her allocated share of Partnership income for any year may exceed the Partnership
distributions to that Limited Partner for the year. 


 Operational Risks: 

 

	 	•	 	 The search for oil and gas is highly speculative and the drilling activities conducted by the Partnership may result in wells that may be dry or wells
that do not produce sufficient oil and gas to produce a profit or result in a return of the Limited Partners’ investment. 


  

	 	•	 	 Certain hazards are encountered in drilling wells, some of which could lead to substantial liabilities to third parties or governmental entities. Also,
governmental regulations or new laws relating to drilling and environmental matters could increase Partnership costs, delay or prevent drilling a well, require the Partnership to cease operations in certain areas or expose the Partnership to
significant liabilities for violations of laws and regulations. 


 Additional Financing 

Additional Assessments. After the Aggregate Subscription has been fully expended or committed and the General Partner’s Minimum Capital
Contribution has been fully expended, the General Partner may make one or more calls for Additional Assessments if additional funds are required to pay the Limited Partners’ share of Drilling Costs, Special Production and Marketing Costs or
Leasehold Acquisition Costs. The maximum amount of total Additional Assessments which may be called for by the General Partner is $100 per Unit. See “ADDITIONAL FINANCING — Additional Assessments.” 

Partnership Borrowings. After the General Partner’s Minimum Capital Contribution has been expended, the General Partner may cause the
Partnership to borrow funds required to pay Drilling Costs, Special Production and Marketing Costs or Leasehold Acquisition Costs of Productive properties. The General Partner may also, but is not required to, advance funds to the Partnership to pay
those costs. See “ADDITIONAL FINANCING — Partnership Borrowings.” 

  
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 Proposed Activities 
 General. The Partnership is being formed for the purposes of conducting oil and gas drilling and development operations and acquiring producing oil and gas properties. The Partnership will,
with certain limited exceptions, participate on a proportionate basis with UPC in each producing oil and gas lease acquired and in each oil and gas well participated in by UPC for its own account during the period from January 1, 2011, if the
Partnership is formed before that date, or from the date of the formation of the Partnership if formed after January 1, 2011, until December 31, 2011, and will, with certain limited exceptions, serve as a co-general partner with UPC in any
drilling or income programs which may be formed by the General Partner in 2011. See “PROPOSED ACTIVITIES.” 
 Partnership
Objectives. The Partnership is being formed to provide eligible employees and directors the opportunity to participate in the oil and gas exploration and producing property acquisition activities of UPC during 2011. UNIT hopes that
participation in the Partnership will provide the participants with greater proprietary interests in UPC’s operations and the potential for realizing a more direct benefit in the event these operations prove to be profitable. The Partnership
has been structured to achieve the objective of providing the Limited Partners with essentially the same economic returns that UPC realizes from the wells drilled or acquired during 2011. 
 Application of Proceeds 
 The offering proceeds will be used to pay the Leasehold
Acquisition Costs incurred by the Partnership to acquire those producing oil and gas leases in which the Partnership participates and the Leasehold Acquisition Costs, exploration, drilling and development costs incurred by the Partnership under the
drilling activities in which the Partnership participates. The General Partner estimates (based on historical operating experience) that those costs will be expended as shown below based on the assumption of a maximum number of subscriptions in the
first column and a minimum number of subscriptions in the second column: 
  

									
	 	  	$900,000
Program	 	  	$50,000
Program	 
	 Leasehold Acquisition Costs of Properties to Be Drilled
	  	$	45,000	  	  	$	2,500	  
			
	 Drilling Costs of Exploratory Wells(1)
	  	 	45,000	  	  	 	2,500	  
			
	 Drilling Costs of Development Wells(1)
	  	 	630,000	  	  	 	35,000	  
			
	 Leasehold Acquisition Costs of Productive Properties
	  	 	180,000	  	  	 	10,000	  
			
	 Reimbursement of General Partner’s Overhead Costs(2)
	  	 	—  	  	  	 	—  	  
		  	 	 	 	  	 	 	 
			
	 Total
	  	$	900,000	  	  	$	50,000	  

  

	(1)	See “GLOSSARY.” 


	(2)	The Agreement provides that the General Partner will be reimbursed by the Partnership for that part of its general and administrative overhead expense attributable to
the conduct of Partnership business and affairs but that any reimbursement will be made only out of Partnership Revenue. See “COMPENSATION.” 


  
 4 








 Participation in Costs and Revenues 
 Partnership costs, expenses and revenues will be allocated among the Partners in the following percentages: 
  

									
	 	  	General
Partner	 	 	Limited
Partners	 
	 COSTS AND EXPENSES
	  				 			
			
	 Organizational and offering costs of the Partnership and any drilling or income programs in which the Partnership
participates as a co-general partner
	  	 	100	% 	 	 	0	% 
			
	 All other Partnership costs and expenses
	  				 			
			
	 Prior to time Limited Partner Capital Contributions are entirely expended
	  	 	1	% 	 	 	99	% 
			
	 After expenditure of Limited Partner Capital Contributions and until expenditure of General Partner’s Minimum Capital
Contribution
	  	 	100	% 	 	 	0	% 
			
	 After expenditure of General Partner’s Minimum Capital Contribution
	  	 
  
	General Partner’s

Percentage(1)

	  
   
	 	 
  
	Limited Partners’

Percentage(1)

	  
   

			
	 REVENUES
	  	 
  
	General Partner’s
 Percentage(1)
	  
   
	 	 
  
	Limited Partners’
 Percentage(1)
	  
   



 

	(1)	See “GLOSSARY.” 

 Compensation

 The General Partner will not receive any management fees in connection with the operation of the Partnership. The Partnership will
reimburse the General Partner for that portion of its general and administrative overhead expense attributable to its conduct of Partnership business and affairs. See “COMPENSATION.” 

Federal Income Tax Considerations; Opinion of Counsel 
 The General Partner has received an opinion from its tax counsel, Conner & Winters, LLP (“Conner & Winters”), concerning all material federal income tax issues applicable to an
investment in the Partnership. To be fully understood, the complete discussion of these matters set forth in the full tax opinion in Exhibit B should be read by each prospective investor. Based on current (as of the date of this Memorandum) laws,
regulations, interpretations, and court decisions, Conner & Winters has rendered its opinion that (i) the material federal income tax benefits in the aggregate from an investment in the Partnership will be realized; (ii) the
Partnership will be treated as a partnership for federal income tax purposes and not as a corporation, an association taxable as a corporation or a publicly traded partnership; (iii) to the extent the Partnership’s wells are timely drilled
and its drilling costs are timely paid, then subject to the limitations on deductions discussed in such opinion, the Partners will be entitled to their pro rata shares of the Partnership’s intangible drilling and development costs
(“IDC”) paid in 2011; (iv) for most Limited Partners, the Partnership’s operations will be considered a passive activity within the meaning of Section 469 of the Internal Revenue Code of 1986, as amended (the
“Code”), and losses generated therefrom will be limited by the passive activity provisions of the Code; and (v) to the extent provided in the opinion, the Partners’ distributive shares of Partnership tax items will be determined
and allocated substantially in accordance with the terms of the Partnership Agreement. 
 Due to the lack of authority regarding, or the
essentially factual nature of certain issues, Conner & Winters expresses no opinion on the following: (i) the impact of an investment in the Partnership on an investor’s alternative minimum tax liability; (ii) whether any
interest incurred by a Partner with respect to any borrowings incurred to purchase Units will be deductible or subject to limitations on deductibility; and (iii) whether the Partnership will be treated as the tax owner of Partnership Properties
acquired by the General Partner as nominee for the Partnership. 

  
 5 








 The opinion of Conner & Winters was not intended or written to be used, and cannot be used, for
the purpose of avoiding penalties that may be imposed by the Service. The opinion of Conner & Winters was written to support the promotion or marketing of Units in the Partnership. Prospective investors should seek advice based on their
particular circumstances from an independent tax advisor. 
 THIS MEMORANDUM CONTAINS AN EXPLANATION OF THE MORE
SIGNIFICANT TERMS AND PROVISIONS OF THE AGREEMENT OF LIMITED PARTNERSHIP WHICH IS ATTACHED AS EXHIBIT A. THE SUMMARY OF THE AGREEMENT CONTAINED IN THIS MEMORANDUM IS QUALIFIED IN ITS ENTIRETY BY SUCH REFERENCE AND ACCORDINGLY THE AGREEMENT SHOULD BE
CAREFULLY REVIEWED AND CONSIDERED. 
 RISK FACTORS 
 Prospective purchasers of Units should carefully study the information contained in this Memorandum and should make their own evaluations of the probability for the discovery of oil and natural gas
through exploration. 
 INVESTMENT RISKS 
 Financial Risks of Drilling Operations 
 The Partnership will participate with the
General Partner (including, with certain limited exceptions, other drilling programs sponsored by it) and, in many cases, other parties (“joint interest parties”) in connection with drilling operations conducted on properties in which the
Partnership has an interest. It is not anticipated that all, if any, of these drilling operations will be conducted under turnkey drilling contracts and, thus, all of the parties participating in the drilling operations on a particular property,
including the Partnership, will be fully liable for their proportionate share of all the costs of those operations even if the actual costs are much more than the original cost estimates. Further, if any joint interest party fails to pay its share
of the costs, the other joint interest parties may be required to pay the deficiency until, if ever, it can be collected from the defaulting party. As a result of forced pooling or similar proceedings (see “COMPETITION, MARKETS AND
REGULATION”), the Partnership may acquire a larger ownership interest in certain Partnership Properties than originally anticipated and, thus, be required to bear a greater share of the costs of operations. Because of the foregoing, the
Partnership could become liable for amounts significantly more than the amounts originally anticipated to be spent in connection with its operations and would have only limited means for providing the additional needed funds (see “ADDITIONAL
FINANCING”). Also, if a company that operates a Partnership Well does not or cannot pay the costs and expenses of drilling or operating the well, the Partnership’s interest in that well may become subject to liens and claims of creditors
who supplied services or materials in connection with such operations even though the Partnership may have previously paid its share of such costs and expenses to the operator. If the operator is unable or unwilling to pay the amount due, the
Partnership might have to pay its share of the amounts owing to such creditors in order to preserve its interest in the well which would mean that it would, in effect, be paying for certain of such costs and expenses twice. 

Dependence on General Partner 

The Limited Partners will acquire interests in the Partnership, not in the General Partner or UNIT. Limited Partners will not participate in either
increases or decreases in the General Partner’s or UNIT’s net worth or the value of either’s common stock. Nevertheless, because the General Partner is primarily responsible for the proper conduct of the Partnership’s business
and affairs and is obligated to provide certain funds that will be required in connection with the Partnership’s operations, a significant reversal of the General Partners or UNIT’s finances could have an adverse effect on the Partnership
and the Limited Partners’ interests in the Partnership. 
 Under the Agreement, UPC is designated as the General Partner of the Partnership
and is given the exclusive authority to manage and operate the Partnership’s business. See “SUMMARY OF THE LIMITED PARTNERSHIP AGREEMENT — Power and Authority”. Accordingly, Limited Partners must rely solely on the General
Partner to make all decisions on behalf of the Partnership, since the Limited Partners will have no role in the management of the business of the Partnership. 

  
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 The Partnership’s success will depend, in part, on the management provided by the General Partner, the
ability of the General Partner to select and acquire oil and gas properties on which Partnership Wells capable of producing oil and natural gas in commercial quantities may be drilled, to fund the acquisition of revenue producing properties, and to
market oil and natural gas produced from Partnership Wells. 
 Conflicts of Interest 

Certain of UNIT’s subsidiaries have engaged in oil and gas exploration and development and in the acquisition of producing properties for their own
account and as the sponsors of drilling and income programs formed with third party investors. It is anticipated that those subsidiaries will continue to engage in those activities. However, with certain exceptions, it is likely that the Partnership
will participate as a working interest owner in all producing oil and gas leases acquired and in all oil and gas wells participated in by the General Partner for its own account during the period from January 1, 2011 (if the Partnership is
formed before that date) or from the date of the formation of the Partnership, if after January 1, 2011, through December 31, 2011 and, with certain limited exceptions, will be a co-general partner of any drilling or income programs, or
both, formed by the General Partner or UNIT in 2011. The General Partner will determine which prospects will be acquired or drilled. With respect to prospects to be drilled, certain of the wells which are drilled for the separate account of the
Partnership and the General Partner may be drilled on prospects on which initial drilling operations were conducted by the General Partner before the formation of the Partnership. Further, certain Partnership Wells will be drilled on prospects on
which the General Partner and possibly future employee programs may conduct additional drilling operations in years after 2011. Except with respect to its participation as a co-general partner of any drilling or income program sponsored by the
General Partner or UNIT, the Partnership will have an interest only in those wells started in 2011 and will have no rights in production from wells started in years other than 2011. Likewise, if additional interests are acquired in wells
participated in by the Partnership after 2011, the Partnership will generally not be entitled to share in the acquisition of those additional interests. See “CONFLICTS OF INTEREST — Acquisition of Properties and Drilling Operations.”

 The Partnership may enter into contracts for the drilling of some or all of the Partnership Wells with affiliates of the General Partner.
Likewise the Partnership may sell or market some or all of its natural gas production to an affiliate of the General Partner. These contracts may not necessarily be negotiated on an arm’s - length basis. The General Partner is subject to a
conflict of interest in selecting an affiliate of the General Partner to drill the Partnership Wells and/or market the natural gas therefrom. The compensation under these contracts will be determined at the time each contract is made. The costs to
be paid or the sale price to be received under each contract will be competitive with the costs charged or the prices paid by unaffiliated parties in the same general geographic region. The General Partner will make the determination of what are
competitive rates or prices. No provision has been made for an independent review of the fairness and reasonableness of such compensation. See “CONFLICTS OF INTERESTS — Transactions with the General Partner or Affiliates.” 

Prohibition on Transferability; Lack of Liquidity 
 Except for certain transfers (i) to the General Partner, (ii) to or for the benefit of the transferor Limited Partner or members of his or her immediate family sharing the same residence, and
(iii) by reason of death or operation of law, a Limited Partner may not transfer or assign Units. The General Partner has agreed that it will, if requested at any time after December 31, 2011, buy Units for prices determined either by an
independent petroleum engineering firm or the General Partner using the formula described under “TERMS OF THE OFFERING — Right of Presentment.” The General Partner’s obligation to purchase Units is limited and does not assure the
liquidity of a Limited Partner’s investment, and the price received may be less than if the Limited Partner continued to hold his or her Units. In addition, similar commitments by the General Partner have been made (and may hereafter be made)
to investors in other oil and gas drilling, income and employee programs. There can be no assurance that the General Partner will have the financial resources to honor its repurchase commitments. See “TERMS OF THE OFFERING — Right of
Presentment.” 

  
 7 








 Delay of Cash Distributions 
 For income tax purposes, a Limited Partner must report his or her distributive (allocated) share of the income, gains, losses and deductions of the Partnership whether or not cash distributions are made.
No cash distributions are expected to be made earlier than the first quarter of 2011. In addition, to the extent that the Partnership uses its revenues to repay borrowings or to finance its activities (see “ADDITIONAL FINANCING”), the
funds available for cash distributions by the Partnership will be reduced or may be unavailable. It is possible that the amount of tax payable by a Limited Partner on his or her distributive share of the income of the Partnership will exceed his or
her cash distributions from the Partnership. See “FEDERAL INCOME TAX CONSIDERATIONS.” 
 If and when any distributions commence and
their subsequent timing or amount cannot be accurately predicted. The decision as to whether or not the Partnership will make a cash distribution at any particular time will be made solely by the General Partner. 

Limitations on Voting and Other Rights of Limited Partners 
 The Agreement, as permitted under the Uniform Limited Partnership Act of 2010 (the “Act”), eliminates or limits the rights of the Limited Partners to take certain actions, such as: 

 

	•	 	 withdrawing from the Partnership, 


  

	•	 	 transferring Units without restrictions, or 


  

	•	 	 consenting to or voting on certain matters such as: 


  

	 	(i)	admitting a new General Partner, 

  

	 	(ii)	admitting Substituted Limited Partners, and 

  

	 	(iii)	dissolving the Partnership. 

 Furthermore, the
Agreement imposes restrictions on the exercise of voting rights granted to Limited Partners. See “SUMMARY OF THE LIMITED PARTNERSHIP AGREEMENT — Voting Rights.” Without the provisions to the contrary which are contained in the
Agreement, the Act provides that certain actions can be taken only with the consent of all Limited Partners. Those provisions of the Agreement which provide for or require the vote of the Limited Partners generally permit the approval of a proposal
by the vote of Limited Partners holding a majority of the outstanding Units. See “SUMMARY OF THE LIMITED PARTNERSHIP AGREEMENT — Voting Rights.” Thus, Limited Partners who do not agree with or do not wish to be subject to the proposed
action may nevertheless become subject to the action if the required majority approval is obtained. Notwithstanding the rights granted to Limited Partners under the Agreement and the Act, the General Partner retains substantial discretion as to the
operation of the Partnership. 
 Rollup or Consolidation of Partnership 
 Under the terms of the Agreement, at any time two years or more after the Partnership has completed substantially all of its property acquisition, drilling and development operations, the General Partner
is authorized to cause the Partnership to transfer its assets to, or to merge or consolidate with, another partnership or a corporation or other entity for the purpose of combining the oil and gas properties and other assets of the Partnership with
those of other partnerships formed for investment or participation by the employees, directors and/or consultants of UNIT or any of its subsidiaries. Such transfer or combination may be effected without the vote, approval or consent of the Limited
Partners. In such event, the Limited Partners will receive interests in the transferee or resulting entity which will mean that they will most likely participate in the results of a larger number of properties but will have proportionately smaller
allocable interests therein. Any such transaction is required to be effected in a manner which UNIT and the General Partner believe is fair and equitable to the Limited Partners but there can be no assurance that such transaction will in fact be in
the best interests of the Limited Partners. Limited Partners have no dissenters’ or appraisal rights under the terms of the Agreement or the Act. Such a transaction would result in the termination and dissolution of the Partnership. While there
can be no assurance that the Partnership will participate in such a transaction, the General Partner currently anticipates that the Partnership will, at the appropriate time, be involved in such a transaction. See “TERMS OF OFFERING,” and
“SUMMARY OF THE LIMITED PARTNERSHIP AGREEMENT.” 

  
 8 








 Partnership Borrowings 
 The General Partner has the authority to cause the Partnership to borrow funds to pay certain costs of the Partnership. While the use of financing to preserve the Partnership’s equity in oil and gas
properties will be intended to increase the Partnership’s profits, such financing could have the effect of increasing the Partnership’s losses if the Partnership is unsuccessful. In addition, the Partnership may have to mortgage its oil
and gas properties and other assets in order to obtain additional financing. If the Partnership defaults on such indebtedness, the lender may foreclose and the Partnership could lose its investment in such oil and gas properties and other assets.
See “ADDITIONAL FINANCING — Partnership Borrowings.” 
 Limited Liability 

Under the Act a Limited Partner’s liability for the obligations of the Partnership is limited to such Limited Partner’s Capital Contribution and
such Limited Partner’s share of Partnership assets. In addition, if a Limited Partner receives a return of any part of his or her Capital Contribution, such Limited Partner is generally liable to the Partnership for a period of one year
thereafter (or six years in the event such return is in violation of the Agreement) for the amount of the returned contribution. A Limited Partner 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 the Partnership. 
 The Agreement provides that by a vote of a majority in interest, the Limited Partners may effect certain changes in the Partnership such as termination and dissolution of the Partnership and amendment of
the Agreement. The exercise of any of these and certain other rights is conditioned on receipt of an opinion by Conner & Winters, LLP for the Limited Partners or an order or judgment of a court of competent jurisdiction to the effect that
the exercise of such rights will not result in the loss of the limited liability of the Limited Partners or cause the Partnership to be classified as an association taxable as a corporation (see “SUMMARY OF THE LIMITED PARTNERSHIP AGREEMENT
— Amendments” and “SUMMARY OF THE LIMITED PARTNERSHIP AGREEMENT — Termination”). As a result of certain judicial opinions it is not clear that these rights will ever be available to the Limited Partners. Nevertheless, in
spite of the receipt of any such opinion or judicial order, it is still possible that the exercise of any such rights by the Limited Partners may result in the loss of the Limited Partners’ limited liability. The Partnership will be governed by
the Act. The Act expressly permits limited partners to vote on certain specified partnership matters without being deemed to be participating in the control of the Partnership’s business and, thus, should result in greater certainty and more
easily obtainable opinions of Conner & Winters regarding the exercise of most of the Limited Partners’ rights. 
 If the
Partnership is dissolved and its business is not to be continued, the Partnership will be wound up. In connection with the winding up of the Partnership, all of its properties may be sold and the proceeds thereof credited to the accounts of the
Partners. Properties not sold will, on termination of the Partnership, be distributed to the Partners. The distribution of Partnership Properties to the Limited Partners would result in their having unlimited liability with respect to such
properties. See “SUMMARY OF THE LIMITED PARTNERSHIP AGREEMENT — Limited Liability.” 
 Partnership Acting as Co-General
Partner 
 It is anticipated that the Partnership will serve as a co-general partner in any drilling or income programs formed by the
General Partner or UNIT during 2011. See “PROPOSED ACTIVITIES.” Accordingly, the Partnership generally will be liable for the obligation and recourse liabilities of any such drilling or income program formed. While a Limited Partner’s
liability for such claims will be limited to such Limited Partners Capital Contribution and share of Partnership assets, such claims if satisfied from the Partnership’s assets could adversely affect the operations of the Partnership.


  
 9 








 Past-Due Installments; Acceleration; Additional Assessments 

Installments and Additional Assessments (see “ADDITIONAL FINANCING”) are legally binding obligations and past-due amounts will bear interest at
the rate set forth in the Agreement; provided, however, that if the General Partner determines that the total Aggregate Subscription is not required to fund the Partnership’s business and operations, then the General Partner may, at its sole
option, elect to release the Limited Partners from their obligation to pay one or more Installments and amend any relevant Partnership documents accordingly. It is anticipated that the total Aggregate Subscription will be required to fund the
Partnership’s business and operations. In the event an Installment is not paid when due and the General Partner has not released the Limited Partners from their obligation to pay such Installment, then the General Partner may, at its sole
option, purchase all Units of the director or employee who fails to pay such Installment, at a price equal to the amount of the prior Installments paid by such person. The General Partner may also bring legal proceedings to collect any unpaid
Installments or Additional Assessments not waived by it. In addition, as indicated under “TERMS OF THE OFFERING — Payment for Units; Delinquent Installment,” if an employee’s employment with or position as a director of the
General Partner, UNIT or any affiliate thereof is terminated other than by reason of Normal Retirement (see “GLOSSARY”), death or disability prior to the time the full amount of the subscription price for his or her Units has been paid,
all unpaid Installments not waived by the General Partner as described above will become due and payable on such termination. 

Partnership Funds 
 Except for
Capital Contributions, Partnership funds are expected to be commingled with funds of the General Partner or UNIT. Thus, Partnership funds could become subject to the claims of creditors of the General Partner or UNIT. The General Partner believes
that its assets and net worth are such that the risk of loss to the Partnership by virtue of such fact is minimal but there can be no assurance that the Partnership will not suffer losses of its funds to creditors of the General Partner or UNIT.

 Compliance with Federal and State Securities Laws 
 This offering has not been registered under the Securities Act of 1933, as amended, in reliance on exemptions from the registration provisions of that act. Further, these interests are being sold pursuant
to exemptions from registration in the various states in which they are being offered and may be subject to additional restrictions in such jurisdictions on transfer. There is no assurance that the offering presently qualifies or will continue to
qualify under such exemptions due to, among other things, the adequacy of disclosure and the manner of distribution of the offering, the existence of similar offerings conducted by the General Partner or UNIT or its affiliates in the past or in the
future, a failure or delay in providing notices or other required filings, the conduct of other oil and gas activities by the General Partner or UNIT and its affiliates or the change of any securities laws or regulations. 

If and to the extent suits for rescission are brought and successfully concluded for failure to register this offering or other offerings under the
Securities Act of 1933, as amended, or state securities acts, or for acts or omissions constituting certain prohibited practices under any of said acts, both the capital and assets of the General Partner and the Partnership could be adversely
affected, thus jeopardizing the ability of the Partnership to operate successfully. Further, the time and capital of the General Partner could be expended in defending an action by investors or by state or federal authorities even where the
Partnership and the General Partner are ultimately exonerated. 
 Title to Properties 

The Partnership Agreement empowers the General Partner, UNIT or any of their affiliates, to hold title to the Partnership Properties for the benefit of
the Partnership. As such it is possible that the Partnership Properties could be subject to the claims of creditors of the General Partner. The General Partner is of the opinion that the likelihood of the occurrence of such claims is remote.
However, the Partnership Property could be subject to claims and litigation in the event that the General Partner failed to pay its debts or became subject to the claims of creditors. 
 Use of Partnership Funds to Exculpate and Indemnify the General Partner 
 The
Agreement contains certain provisions which are intended to limit the liability of the General Partner and its affiliates for certain acts or omissions within the scope of the authority conferred on them by the Agreement. In addition, under the
Agreement, the General Partner will be indemnified by the Partnership against losses, 

  
 10 









 
judgments, liabilities, expenses and amounts paid in settlement sustained by it in connection with the Partnership so long as the losses, judgments, liabilities, expenses or amounts were not the
result of gross negligence or willful misconduct on the part of the General Partner. See “SUMMARY OF THE LIMITED PARTNERSHIP AGREEMENT — Exculpation and Indemnification of the General Partner.” 

The Partnership Agreement May Limit the Fiduciary Obligation of the General Partner to the Partnership and the Limited Partners 

The Agreement contains certain provisions which modify what would otherwise be the applicable Oklahoma law relating to the fiduciary standards of the
General Partner to the Limited Partners. The fiduciary standards in the Agreement could be less advantageous to the Limited Partners and more advantageous to the General Partner than the corresponding fiduciary standards otherwise applicable under
Oklahoma law (although there are very few legal precedents clarifying exactly what fiduciary standards would otherwise be applicable under Oklahoma law). The purchase of Units may be deemed as consent to the fiduciary standards set forth in the
Agreement. See “FIDUCIARY RESPONSIBILITY.” As a result of these provisions in the Agreement, the Limited Partners may find it more difficult to hold the General Partner responsible for acting in the best interest of the Partnership and the
Limited Partners than if the fiduciary standards of the otherwise applicable Oklahoma law governed the situation. 
 TAX STATUS AND TAX
RISKS 
 It is possible that the tax treatment currently available with respect to oil and gas exploration and production will be
modified or eliminated on a retroactive or prospective basis by legislative, judicial, or administrative actions. The limited tax benefits associated with oil and gas exploration do not eliminate the inherent economic risks. 

Partnership Classification 

Conner & Winters has rendered its opinion that the Partnership will be classified for federal income tax purposes as a partnership and not as a
corporation, an association taxable as a corporation or a “publicly traded partnership.” Such opinion is not binding on the Service or the courts. If the Partnership were classified as a corporation, association taxable as a corporation or
publicly traded partnership, any income, gain, loss, deduction, or credit of the Partnership would remain at the entity level, and not flow through to the Partners, the income of the Partnership would be subject to corporate tax rates at the entity
level and distributions to the Partners could be considered dividend distributions. See “Federal Income Tax Considerations—General Tax Effects of Partnership Structure.” 
 Limited Partner Interests 
 It is anticipated that in the first year(s) of the
Partnership, Limited Partners will be allocated deductions in excess of their allocations of income. An investment as a Limited Partner may not be advisable for a person who does not anticipate having substantial current taxable income from passive
trade or business activities (not counting dividend or interest income). Most Limited Partners will be subject to the “passive activity loss” rules. A Limited Partner subject to the passive activity loss rules will be unable to use passive
losses generated by the Partnership until and unless he or she has realized “passive income”. 
 Tax Liabilities in Excess of
Cash Distributions 
 A Limited Partner must include in his or her own income tax return his or her share of the items of the
Partnership’s income, gain, profit, loss, and deductions whether or not cash proceeds are actually distributed to the Partner to pay any tax resulting from the Partnership’s income or gain. For example, income from the Partnership’s
sale of oil and gas production will be taxable to Limited Partners as ordinary income subject to depletion and other deductions whether or not the proceeds from such sale are actually distributed. 

Items Not Covered by the Tax Opinion 
 Due to the lack of authority regarding, or the essentially factual nature of certain issues, Conner & Winters has expressed no opinion as to the following: (i) the impact of an investment in
the Partnership on an investor’s alternative minimum tax liability; (ii) whether any of the Partnership’s properties will be considered “proven” for purposes of depletion deductions; and (iii) whether the Partnership
will be treated as the tax owner of Partnership Properties acquired by the General Partner as nominee for the Partnership. 

  
 11 









 Tax Opinion Not Binding on Service 
 Prospective investors should recognize that an opinion of legal counsel merely represents such counsel’s best legal judgment under existing statutes, judicial decisions, and administrative
regulations and interpretations. There can be no assurance that deductions claimed by the Partnership in reliance on the opinion of Conner & Winters will not be challenged successfully by the Service. 

The opinion of Conner & Winters was not intended or written to be used, and cannot be used, for the purpose of avoiding penalties that may be
imposed by the Service. The opinion of Conner & Winters was written to support the promotion or marketing of Units in the Partnership. Prospective investors should seek advice based on their particular circumstances from an independent tax
advisor. 
 OPERATIONAL RISKS 
 Risks Inherent in Oil and Gas Operations 
 The Partnership will be participating with
the General Partner in acquiring producing oil and gas leases and in the drilling of those oil and gas wells commenced by the General Partner from the later of January 1, 2011 or the time the Partnership is formed through December 31, 2011
and, with certain limited exceptions, serving as a co-general partner of any oil and gas drilling or income programs, or both, formed by the General Partner or UNIT during 2011. 
 All drilling to establish productive oil and natural gas properties is inherently speculative. The techniques presently available to identify the existence and location of pools of oil and natural gas are
indirect, and, therefore, a considerable amount of personal judgment is involved in the selection of any prospect for drilling. The economics of oil and natural gas drilling and production are affected or may be affected in the future by a number of
factors which are beyond the control of the General Partner, including (i) the general demand in the economy for energy fuels, (ii) the worldwide supply of oil and natural gas, (iii) the price of, as well as governmental policies with
respect to, oil and liquefied natural gas imports, (iv) potential competition from competing alternative fuels, (v) governmental regulation of prices for oil and natural gas production, gathering and transportation, (vi) state
regulations affecting allowable rates of production, well spacing and other factors such as, but not limited to, regulation of gathering, (vii) proximity to and capacity available on oil and gas pipelines, and (viii) availability of
drilling rigs, casing and other necessary goods and services. See “COMPETITION, MARKETS AND REGULATION.” The revenues, if any, generated from Partnership operations will be highly dependent on the future prices and demand for oil and
natural gas. The factors enumerated above affect, and will continue to affect, oil and natural gas prices. Recently, prices for oil and natural gas have fluctuated over a wide range. 
 Operating and Environmental Hazards 
 Operating hazards such as fires, explosions,
blowouts, unusual formations, formations with abnormal pressures and other unforeseen conditions are sometimes encountered in drilling wells. On occasion, substantial liabilities to third parties or governmental entities may be incurred, the payment
of which could reduce the funds available for exploration and development or result in loss of Partnership Properties. The Partnership will attempt to maintain customary insurance coverage, but the Partnership may be subject to liability for
pollution and other damages or may lose substantial portions of its properties due to hazards against which it cannot insure or against which it may elect not to insure due to unreasonably high or prohibitive premium costs or for other reasons. The
activities of the Partnership may expose it to drilling limitations and potential liability for pollution or other damages under laws and regulations relating to environmental matters (see “Government Regulation and Environmental Risks”
below). 

  
 12 









 Competition 
 The oil and gas industry is highly competitive. The Partnership will be involved in intense competition for the acquisition of quality undeveloped leases and producing oil and gas properties. There can be
no assurance that a sufficient number of suitable oil and gas properties will be available for acquisition or development by the Partnership. The Partnership will be competing with numerous major and independent companies which possess financial
resources and staffs larger than those available to it. The Partnership, therefore, may be unable in certain instances to acquire desirable leases or supplies or may encounter delays in commencing or completing Partnership operations. 

Markets for Oil and Natural Gas Production 
 Historically, oil and gas prices have been extremely volatile, with significant increases and significant price drops being experienced from time to time. Oil and gas prices have continued relatively
lower compared to prices in the past during recent months due to the continued slow national and global economic environment. The current economic environment and the continued lower commodity prices are causing the General Partner (and other oil
and gas companies) to reduce their overall level of drilling activity and spending. A continued sluggish national and global economy will also result (to varying degrees) in a reduction in the demand for oil and gas products by those industries and
consumers that use those products in their business operations. The degree to which that demand is reduced and for how long it may last are unknown at this time. Significant reductions in demand for oil and gas would result in lower prices for our
products and force us to curtail our production of those products which, in turn, would affect our financial results. In the future, various factors beyond the control of the Partnership will have a significant effect on oil and gas prices. Such
factors include, among other things, uncertainty in the national and global economic markets, the domestic and foreign supply of oil and gas, the price of foreign imports, the levels of demand for oil and gas products, the price and availability of
alternative fuels, the availability of pipeline capacity, changes in existing and proposed federal regulation and price controls, and the volatility of spot prices and commodity markets for oil and gas. 

Due to the uncertainty in the energy markets, it is possible that prices for oil produced in the future will be higher or lower than those currently
available. There can be no assurance that the oil the Partnership produces can be marketed on favorable price and other contractual terms. See “COMPETITION, MARKETS AND REGULATION — Marketing of Production.” 

The natural gas market is also unsettled due to a number of factors. In the past, production from natural gas wells in some geographic areas of the
United States was curtailed for considerable periods of time due to a lack of market demand. Over the past several years demand for natural gas has increased greatly limiting the number of wells being shut in for lack of demand and also has resulted
in higher lease acquisition costs. It is possible, however, that Partnership Wells may in the future be shut-in or that natural gas will be sold on terms less favorable than might otherwise be obtained should demand for gas lessen in the future.
Competition for available markets has been vigorous and there remains great uncertainty about prices that purchasers will pay. Natural gas surpluses could result in the Partnership’s inability to market natural gas profitably, causing
Partnership Wells to curtail production and/or receive lower prices for its natural gas, situations which would adversely affect the Partnership’s ability to make cash distributions to its participants. See “COMPETITION, MARKETS AND
REGULATION.” 
 In the event that the Partnership discovers or acquires natural gas reserves, there may be delays in commencing or
continuing production due to the need for gathering and pipeline facilities, contract negotiation with the available market, pipeline capacities, seasonal takes by the gas purchaser or a surplus of available gas reserves in a particular area.

 Government Regulation and Environmental Risks 
 The oil and gas business is subject to pervasive government regulation under which, among other things, rates of production from producing properties may be fixed and the prices for gas produced from such
producing properties may be impacted. It is possible that these regulations pertaining to rates of production could become more pervasive and stringent in the future. The activities of the Partnership may expose it to potential liability under laws
and regulations relating to environmental matters which could adversely affect the Partnership. Compliance with these laws and regulations may increase Partnership costs, delay or prevent the drilling of wells, delay or prevent the acquisition of
otherwise desirable producing oil and gas properties, require the Partnership to cease operations in certain areas, and cause delays in the production of oil and gas. See “COMPETITION, MARKETING AND REGULATION.” 

  
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 Leasehold Defects 
 In certain instances, the Partnership may not be able to obtain a title opinion or report with respect to a producing property that is acquired. Consequently, the Partnership’s title to any such
property may be uncertain. Furthermore, even if certain technical defects do appear in title opinions or reports with respect to a particular property, the General Partner, in its sole discretion, may determine that it is in the best interest of the
Partnership to acquire such property without taking any curative action. 
 TERMS OF THE OFFERING 

General 
  

	 	•	 	 900 Maximum Units; 50 Minimum Units 


  

	 	•	 	 $1,000 Units; Minimum subscription: $2,000 


  

	 	•	 	 Minimum Partnership: $50,000 in subscriptions 


  

	 	•	 	 Maximum Partnership: $900,000 in subscriptions 


 Limited Partnership Interests 
 The Partnership hereby offers to certain employees
(described under “Subscription Rights” below) and directors of UNIT and its subsidiaries an aggregate of 900 Units. The purchase price of each Unit is $1,000, and the minimum permissible purchase by any eligible subscriber is two Units
($2,000). See “Subscription Rights” below for the maximum number of Units that may be acquired by subscribers. 
 The Partnership will
be formed as an Oklahoma limited partnership on the closing of the offering of Units made by this Memorandum. The General Partner will be Unit Petroleum Company (the “General Partner”, or “UPC”), an Oklahoma corporation.
Partnership operations will be conducted from the General Partner’s offices, the address of which is 7130 South Lewis Avenue, Suite 1000, Tulsa, Oklahoma 74136, telephone (918) 493-7700. 

The offering of Units will be closed on January 21, 2011, unless extended by the General Partner for up to 30 days, and all Units subscribed will be
issued on the Effective Date. The offering may be withdrawn by the General Partner at any time prior to such date if it believes it to be in the best interests of the eligible employees and Directors or the General Partner not to proceed with the
offering. 
 If at least 50 Units ($50,000) are not subscribed prior to the termination of the offering, the Partnership will not commence
business. The General Partner may, on its own accord, purchase Units and, in such capacity, will enjoy the same rights and obligations as other Limited Partners, except the General Partner will have unlimited liability. The General Partner may, in
its discretion, purchase Units sufficient to reach the minimum Aggregate Subscription ($50,000). Because the General Partner or its affiliates might benefit from the successful completion of this offering (see “PARTICIPATION IN COSTS, AND
REVENUES” and “COMPENSATION”), investors should not expect that sales of the minimum Aggregate Subscription indicate that such sales have been made to investors that have no financial or other interest in the offering or that have
otherwise exercised independent investment discretion. Further, the sale of the minimum Aggregate Subscription is not designed as a protection to investors to indicate that their interest is shared by other unaffiliated investors and no investor
should place any reliance on the sale of the minimum Aggregate Subscription as an indication of the merits of this offering. Units acquired by the General Partner will be for investment purposes only without a present intent for resale and there is
no limit on the number of Units that may be acquired by it. 

  
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 Subscription Rights 
 Units are offered only to persons who are salaried employees of UNIT or its subsidiaries at the date of formation of the Partnership and whose annual base salaries for 2010 (excluding bonuses) have been
set at $60,000 or more and to directors of UNIT. Only employees and directors who are U.S. citizens are eligible to participate in the offering. In addition, employees and directors must be able to bear the economic risks of an investment in the
Partnership and must have sufficient investment experience and expertise to evaluate the risks and merits of such an investment. See “PLAN OF DISTRIBUTION — Suitability of Investors.” 

Eligible employees and directors are restricted as to the number of Units they may purchase in the offering. The maximum number of Units which can be
acquired by any employee is that number of whole Units which can be purchased with an amount which does not exceed one-half of the employee’s base salary for 2010; provided, however, that the General Partner may, at its discretion, accept a
subscription for a greater amount. Each director of UNIT may subscribe for a maximum of 300 Units (maximum investment of $300,000). At December 30, 2010 there were approximately 420 people eligible to purchase Units. 

Eligible employees and directors may acquire Units through a corporation or other entity in which all of the beneficial interests are owned by them or
permitted assignees (see “SUMMARY OF THE LIMITED PARTNERSHIP AGREEMENT — Transferability of Interests”); provided that such employees or directors will be jointly and severally liable with such entity for payment of the Capital
Subscription. 
 The number of Units offered is limited and there will not be sufficient Units available if a substantial number of the eligible
employees and directors subscribe for the maximum number of Units. In the event the Units are oversubscribed, Units will be allocated among the respective subscribers in the proportion that each subscription amount bears to total subscriptions
obtained. 
 No employee is obligated to purchase Units in order to remain in the employ of UNIT, and the purchase of Units by any employee will
not obligate UNIT to continue the employment of such employee. Units may be subscribed for by a trust for the minor children of eligible employees and directors. 
 Payment for Units; Delinquent Installment 
 The Capital Subscriptions of the Limited
Partners will be payable either (i) in four equal Installments, the first of such Installments being due on March 15, 2011 and the remaining three of such Installments being due on June 15, September 15, and
December 15, 2011, respectively, or (ii) by employees so electing in the space provided on the Subscription Agreement, through equal deductions from 2011 salary paid to the employee by the General Partner, UNIT or its subsidiaries
commencing immediately after formation of the Partnership. If an employee or director who has subscribed for Units (either directly or through a corporation or other entity) ceases to be employed by or serve as a director of the General Partner,
UNIT or any of its subsidiaries for any reason other than death, disability or Normal Retirement prior to the time the full amount of all Installments not waived by the General Partner as described below are due, then the due date for any such
unpaid Installments shall be accelerated so that the full amount of his or her unpaid Capital Subscription will be due and payable on the effective date of such termination. 
 Each Installment will be a legally binding obligation of the Limited Partner and any past due amounts will bear interest at an annual rate equal to two percentage points in excess of the prime rate of
interest of Bank of Oklahoma, N.A., Tulsa, Oklahoma; provided, however, that if the General Partner determines that the total Aggregate Subscription is not required to fund the Partnership’s business and operations, then the General Partner
may, at its sole option, elect to release the Limited Partners from their obligation to pay one or more Installments (including the obligation to pay in the amount of any Additional Assessments). If the General Partner elects to waive the payment of
an Installment, it will notify all Limited Partners promptly in writing of its decision and will, to the extent required, amend the certificate of limited partnership and any other relevant Partnership documents accordingly. It is currently
anticipated that the total Aggregate Subscription will be required, however, to fund the Partnership’s business and operations. 
 In the
event a Limited Partner fails to pay any Installment when due and the General Partner has not released the Limited Partners from their obligation to pay such Installment, then the General Partner, at its sole option and discretion, may elect to
purchase the Units of such defaulting Limited Partner at a price equal to the total amount of the Capital Contributions actually paid into the Partnership by such defaulting Limited Partner, less the amount of any Partnership distributions that may
have been received by him or her. Such option may be exercised by the General Partner by written notice to the Limited Partner at any time after the date that the unpaid Installment was due and will be deemed exercised when the amount of the
purchase price is first tendered to the defaulting Limited Partner. The General Partner may, in its discretion, accept payments of delinquent Installments not waived by it but will not be required to do so. 

  
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 In the event that the General Partner elects to purchase the Units of a defaulting Limited Partner, it must
pay into the Partnership the amount of the delinquent Installment (excluding any interest that may have accrued thereon) and pay each additional Installment, if any, payable with respect to such Units as it becomes due. By virtue of such purchase,
the General Partner will be allocated all Partnership Revenues, be charged with all Partnership costs and expenses attributable to such Units and will enjoy the same rights and obligations as other Limited Partners, except the General Partner will
have unlimited liability. 
 Right of Presentment 
 After December 31, 2011, and annually thereafter, Limited Partners will have the right to present their Units to the General Partner for purchase. The General Partner will not be obligated to
purchase more than 20% of the then outstanding Units in any one calendar year. The purchase price to be paid for the Units of any Limited Partner presenting them for purchase will be based on the net asset value of the Partnership which shall be
equal to: 
  

	 	(1)	The value of the proved reserves attributable to the Partnership Properties, determined as set forth below; plus 


 

	 	(2)	The estimated salvage value of tangible equipment installed on Partnership Wells less the costs of plugging and abandoning the wells, both discounted at the rate
utilized to determine the value of the Partnership’s reserves as set forth below; plus 

  

	 	(3)	The lower of cost or fair market value of all Partnership Properties to which proved reserves have not been attributed but which have not been condemned, as determined
by an independent petroleum engineering firm or the General Partner, as the case may be; plus 

  

	 	(4)	Cash on hand; plus 

  

	 	(5)	Prepaid expenses and accounts receivable (less a reasonable reserve for doubtful accounts); plus 


 

	 	(6)	The estimated market value of all other Partnership assets not included in (1) through (5) above, determined by the General Partner; MINUS


  

	 	(7)	An amount equal to all debts, obligations and other liabilities of the Partnership. 

 The price to be paid for each Limited Partner’s interest of the net asset value will be his or her proportionate share of such net asset value less 75% of the amount of any distributions received by
him or her which are attributable to the sales of the Partnership production since the date as of which the Partnership’s proved reserves are estimated. 
 The value of the proved reserves attributable to Partnership Properties will be determined as follows: 
  

	 	(i)	First, the future net revenues from the production and sale of the proved reserves will be estimated as of the end of the calendar year in which presentment is made
based on an independent engineering firm’s report and its determinations of the prices to be used as well as the escalations, if any, of such prices and cost or, if no report was made, as determined by the General Partner;


  

	 	(ii)	Next, the future net revenues from the production and sale of proved reserves as determined above will be discounted at an annual rate which is one percentage point
higher than the prime rate of interest being charged by the Bank of Oklahoma, N.A., Tulsa, Oklahoma, or any successor bank, as of the date such reserves are estimated; and 


 

	 	(iii)	Finally, the total discounted value of the future net revenues from the production and sale of proved reserves will be reduced by an additional 25% to take into account
the risks and uncertainties associated with the production and sale of the reserves and other unforeseen uncertainties. 


  
 16 









 A Limited Partner who elects to have his or her Units purchased by the General Partner should be aware that
estimates of future net recoverable reserves of oil and gas and estimates of future net revenues to be received therefrom are based on a great many factors, some of which, particularly future prices of production, are usually variable and uncertain
and are always determined by predictions of future events. Accordingly, it is common for the actual production and revenues received to vary from earlier estimates. Estimates made in the first few years of production from a property will be based on
relatively little production history and will not be as reliable as later estimates based on longer production history. As a result of all the foregoing, reserve estimates and estimates of future net revenues from production may vary from year to
year. 
 This right of presentment may be exercised by written notice from a Limited Partner to the General Partner. The sale will be effective
as of the close of business on the last day of the calendar year in which such notice is given or, at the General Partner’s election, at 7:00 A.M. on the following day. Within 120 days after the end of the calendar year, the General Partner
will furnish each Limited Partner who gave such notice during the calendar year a statement showing the cash purchase price which would be paid for the Limited Partner’s interest as of December 31 of the preceding year, which statement
will include a summary of estimated reserves and future net revenues and sufficient material to reveal how the purchase price was determined. The Limited Partner must, within 30 days after receipt of such statement, reaffirm his or her election to
sell to the General Partner. 
 As noted above, the General Partner will not be obligated to purchase in any one calendar year more than 20% of
the Units in the Partnership then outstanding. Moreover, the General Partner will not be obligated to purchase any Units pursuant to such right if such purchase, when added to the total of all other sales, exchanges, transfers or assignments of
Units within the preceding 12 months, would result in the Partnership being considered to have terminated within the meaning of Section 708 of the Code or would cause the Partnership to lose its status as a partnership or be treated as a
publicly traded partnership for federal income tax purposes. If more than the number of Units which may be purchased are tendered in any one year, the Limited Partners from whom the Units are to be purchased will be determined by lot. Any Units
presented but not purchased with respect to one year will have priority for such purchase the following year. 
 The General Partner does not
intend to establish a cash reserve to fund its obligation to purchase Units, but will use funds provided by its operations or borrowed funds (if available), using its assets (including such Units purchased or to be purchased from Limited Partners)
as collateral to fund such obligations. However, there is no assurance that the General Partner will have sufficient financial resources to discharge its obligations. 
 Rollup or Consolidation of Partnership 
 The Agreement provides that two years or
more after the Partnership has completed substantially all of its property acquisition, drilling and development operations, the General Partner may, without the vote, consent or approval of the Limited Partners, cause all or substantially all of
the oil and gas properties and other assets of the Partnership to be sold, assigned or transferred to, or the Partnership merged or consolidated with, another partnership or a corporation, trust or other entity for the purpose of combining the
assets of two or more of the oil and gas partnerships formed for investment or participation by employees, directors and/or consultants of UNIT or any of its subsidiaries; provided, however, that the valuation of the oil and gas properties and other
assets of all such participating partnerships for purposes of such transfer or combination shall be made on a consistent basis and in a manner which the General Partner and UNIT believe is fair and equitable to the Limited Partners. As a consequence
of any such transfer or combination, the Partnership shall be dissolved and terminated and the Limited Partners shall receive partnership interests, stock or other equity interests in the transferee or resulting entity. Any such action will cause
the Limited Partners’ attributable interest in the Partnership Properties to be diluted but it will also provide them with attributable interests in the properties and other assets of the other partnerships participating in the consolidation.
It also may reduce somewhat the amount of their attributable shares of the direct and indirect costs of administering the Partnership. See “RISK FACTORS — Investment Risks - Roll-Up or Consolidation of Partnership.” 

  
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 ADDITIONAL FINANCING 
 The General Partner will use its best efforts, consistent with Partnership objectives, to acquire Productive properties and complete the Partnership’s drilling and development operations before the
Aggregate Subscription has been fully expended or committed. However, funds in addition to the Aggregate Subscription may be required to pay costs and expenses which are chargeable to the Limited Partners. In those instances described below, the
General Partner may call for Additional Assessments or may apply Partnership Revenue allocable to the Limited Partners in payment and satisfaction of such costs or the General Partner may, but shall not be required to, fund the deficiency with
Partnership borrowings to be repaid with Partnership Revenue. 
 Additional Assessments 

When the Aggregate Subscription has been fully expended or committed, the General Partner may make one or more calls for any portion or all of the maximum
Additional Assessments of $100 per Unit. However, no Additional Assessments may be required before the General Partner’s Minimum Capital Contribution has been fully expended. Such assessments may be used to pay the Limited Partners’ share
of the Drilling Costs, Special Production and Marketing Costs or Leasehold Acquisition Costs of Productive properties which are chargeable to the Limited Partners. The amount of the Additional Assessment so called shall be due and payable on or
before such date as the General Partner may set in such call, which in no event will be earlier than thirty (30) days after the date of mailing of the call. The notice of the call for Additional Assessments will specify the amount of the
assessment being required, the intended use of such funds, the date on which the contributions are payable and describe the consequences of nonpayment. Although the Limited Partners who do not respond will participate in production, if any, obtained
from operations conducted with the proceeds from the aggregate Additional Assessments paid into the Partnership, the amount of the unpaid Additional Assessment shall bear interest at the annual rate equal to two (2) percentage points in excess
of the prime rate of interest of Bank of Oklahoma, N.A., Tulsa, Oklahoma, or successor bank, as announced and in effect from time to time, until paid. The Partnership will have a lien on the defaulting Limited Partner’s interest in the
Partnership and the General Partner may retain Partnership Revenue otherwise available for distribution to the defaulting Limited Partner until an amount equal to the unpaid Additional Assessment and interest is received. Furthermore, the General
Partner may satisfy such lien by proceeding with legal action to enforce the lien and the defaulting Limited Partner shall pay all expenses of collection, including interest, court costs and a reasonable attorney’s fee. If the General Partner
believes that no Additional Assessments will be required to fund the Partnership’s business and operations, it may release the Limited Partners from their obligations to make the Additional Assessments by a notice in writing. 

Prior Programs 
 In the prior
employee programs conducted by UNIT or the General Partner in each of the years 1984 through 2010, Additional Assessments could be called for as provided herein. At September 30, 2010, there had been no calls for Additional Assessments in such
programs. There can be no assurance, however, that Additional Assessments will not be required to pay Partnership costs. The General Partner released the limited partners in the Unit 2007 Oil and Gas Limited Partnership from the obligation to make
any Additional Assessments in excess of $44.00 per Unit. 
 Partnership Borrowings 

At any time after the General Partner’s Minimum Capital Contribution has been fully expended, the General Partner may cause the Partnership to borrow
funds for the purpose of paying Drilling Costs, Special Production and Marketing Costs or Leasehold Acquisition Costs of Productive properties, which borrowings may be secured by interests in the Partnership Properties and will be repaid, including
interest accruing thereon, out of Partnership Revenue. The General Partner may, but is not required to, advance funds to the Partnership for the same purposes for which Partnership borrowings are authorized. With respect to any such advances, the
General Partner will receive interest in an amount equal to the lesser of the interest which would be charged to the Partnership by unrelated banks on comparable loans for the same purpose or the General Partner’s interest cost with respect to
such loan, where it borrows the same. No financing charges will be levied by the General Partner in connection with any such loan. If Partnership borrowings secured by interests in the Partnership Wells and repayable out of Partnership Revenue
cannot be arranged on a basis which, in the opinion of the General Partner, is fair and reasonable, and the entire sum required to pay such costs is not available from Partnership Revenue, the General Partner may dispose of some or all of the
Partnership Properties on which such operations were to be conducted by sale, farm-out or abandonment. 

  
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 If the Partnership requires funds to conduct Partnership operations during the period between any of the
Installments due from the Limited Partners, then, notwithstanding the foregoing, the General Partner shall advance funds to the Partnership in an amount equal to the funds then required to conduct such operations but in no event more than the total
amount of the Aggregate Subscription remaining unpaid. With respect to any such advances, the General Partner shall receive no interest thereon and no financing charges will be levied by the General Partner in connection therewith. The General
Partner shall be repaid out of the Installments thereafter paid into the capital of the Partnership when due. 
 The Partnership may attempt to
finance any expenses in excess of the Partners’ Capital Subscriptions by the foregoing means and any other means which the General Partner deems in the best interests of the Partnership, but the Partnership’s inability to meet such costs
could result in the deferral of drilling operations or in the inability to participate in future drilling or in non-consent penalties pursuant to which co-owners of particular working interests recover several times the amount which would have been
funded by the Partnership in accordance with its ownership interest before the Partnership would participate in revenues. 
 The use of
Partnership Revenue allocable to the Limited Partners to pay Partnership costs and expenses and to repay any Partnership borrowings will mean that such revenue will not be available for distribution to the Limited Partners. Nonetheless, the Limited
Partners may incur income tax liability by virtue of that revenue and, thus, may not receive distributions from the Partnership in amounts necessary to pay such income tax. However, the use of such revenue to pay Partnership costs and expenses may
generate additional deductions for the Limited Partners. 
 PLAN OF DISTRIBUTION 

Units will be offered privately only to select persons who can demonstrate to the General Partner that they have both the economic means and investment
expertise to qualify as suitable investors. The Units will be offered and sold by the officers and directors of UPC or UNIT. 

Suitability of Investors 

Subscriptions should be made only by appropriate persons who can reasonably benefit from an investment in the Partnership. In this regard, a subscription
will generally be accepted only from a person who can represent that such person has (or in the case of a husband and wife, acting as joint tenants, tenants in common or tenants in the entirety, that they have) a net worth, including home,
furnishings and automobiles, of at least five times the amount of his or her Capital Subscription, and estimates that such person will have during the current year adjusted gross income in an amount which will enable him or her to bear the economic
risks of his or her investment in the Partnership. Such person must also demonstrate that he or she has sufficient investment experience and expertise to evaluate the risks and merits of an investment in the Partnership. 

Participation in the Partnership is intended only for those persons willing to assume the risk of a speculative, illiquid, long-term investment.
Entitlement to and maintenance of the exemptions from registration provided by Sections 3(b) and/or 4(2) of the Securities Act of 1933, as amended, require the imposition of certain limitations on the persons to whom offers may be made, and from
whom subscriptions may be accepted. Therefore, this offering is limited to persons who, by virtue of investment acumen or financial resources, satisfy the General Partner that they meet suitability standards consistent with the maintenance and
preservation of the exemptions provided by Sections 3(b) and/or 4(2) and by the applicable rules and regulations of the Securities and Exchange Commission, as well as those contained herein and in the Subscription Agreement. Persons offering
interests shall sufficiently inquire of a prospective investor to be reasonably assured that such investor meets such acceptable standards. Suitability standards may also be imposed by the regulatory authorities of the various states in which
interests may be offered. 

  
 19 









 RELATIONSHIP OF THE PARTNERSHIP, 

THE GENERAL PARTNER AND AFFILIATES 
 The following diagram depicts the primary relationships among the Partnership, the General Partner and certain of its affiliates. 

 

 

 PROPOSED ACTIVITIES 
 General 
 The Partnership will, with certain limited exceptions, participate in all
of UNIT’s or UPC’s oil and gas activities commenced during 2011. The Partnership will acquire 1% of essentially all of UNIT’s interest in such activities. The activities will include (i) participating as a joint working interest
owner with UNIT or UPC in any producing leases acquired and in any wells commenced by UNIT or UPC other than as a general partner in a drilling or income program during 2011 and (ii) serving as a co-general partner in any drilling or income
programs, or both, formed by the General Partner or UNIT during 2011. 
 Acquisition of Properties and Drilling Operations. The
Partnership will participate, to the extent of 1% of UPC or UNIT’s final interest in each well, as a fractional working interest holder in any producing leases acquired and in any drilling operations conducted by UPC or UNIT for its own account
which are acquired or commenced, respectively, from January 1, 2011, or the time of the formation of the Partnership if subsequent to January 1, 2011, until December 31, 2011, except for wells, if any: 

 

	 	(i)	drilled outside the 48 contiguous United States; 

  

	 	(ii)	drilled as part of secondary or tertiary recovery operations which were in existence prior to formation of the Partnership; 


 

	 	(iii)	drilled by third parties under farm-out or similar arrangements with UNIT or the General Partner or whereby UNIT or the General Partner may be entitled to an overriding
royalty, reversionary or other similar interest in the production from such wells but is not obligated to pay any of the Drilling Costs thereof; 


  
 20 










	 	(iv)	acquired by UNIT or the General Partner through the acquisition by UNIT or the General Partner of, or merger of UNIT or the General Partner with, other companies (this
exception may, at the discretion of UNIT or the General Partner, be waived.); or 

  

	 	(v)	with respect to which the General Partner does not believe that the potential economic return therefrom justifies the costs of participation by the Partnership.


 Instances referred to in (v) could occur when UNIT or one of its subsidiaries agrees to participate in the ownership of a
prospect for its own account in order to obtain the contract to drill the well thereon. There may be situations where the potential economic return of the well alone would not be sufficient to warrant participation by UNIT but when considered in
light of the revenues expected to be realized as a result of the drilling contract, such participation is desirable from UNIT’s standpoint. However, in such a situation, the Partnership would not be entitled to any of the revenues generated by
the drilling contract so its participation in the well would not be desirable. 
 For these purposes, the drilling of a well will be deemed to
have commenced on the “spud date,” i.e., the date that the drilling rig is set up and actual drilling operations are commenced. Any clearing or other site preparation operations will not be considered part of the drilling operations for
these purposes. 
 Participation in Drilling or Income Programs. Except for certain limited exceptions it is anticipated that the
Partnership will participate with UPC or UNIT as a co-general partner of any drilling or income programs, or both, formed by UPC or UNIT and its affiliates during 2011. The Partnership will be charged with 1% of the total costs and expenses charged
to the general partners and allocated 1% of the revenues allocable to the general partners in any such program and UPC or UNIT will be charged with the remaining 99% of the general partners’ share of costs and expenses and allocated the
remaining 99% of the general partners’ share of program revenues. 
 UNIT or its affiliates formed drilling programs for outside investors
from 1979 through 1984. In 1987, the Unit 1986 Energy Income Limited Partnership (the “1986 Energy Program”) was formed primarily to acquire interests in producing oil and gas properties. See “PRIOR ACTIVITIES.” All of the
programs were formed as limited partnerships and interests in all of the programs other than the Unit 1979 Oil and Gas Program and the 1986 Energy Program were offered in registered public offerings. The 1979 Program and 1986 Energy Program were
offered privately to a limited number of sophisticated investors. 
 No drilling or income programs for third party investors were formed in
2010. Although it does not currently contemplate doing so, UNIT may form such drilling or income programs during 2011. If such a program is formed, there would be only one or two such programs and they probably would be privately offered. The
precise revenue and cost sharing format of any such programs has not been determined. 
 The cost and revenue sharing provisions of virtually
all drilling programs offered to third parties generally require the limited partners or investors to bear a somewhat higher percentage of the program’s drilling and development costs than the percentage of program revenues to which they are
entitled. Likewise, the general partners will normally receive a higher percentage of revenues than the percentage of drilling and development costs which they are required to pay. The difference in these percentages is often referred to as the
general partners’ “promote.” Any drilling program which UNIT or UPC may form in 2011 for outside investors would likely have some amount of “promote” for the general partner(s). 

Any income program may use the same or a similar format as that used for the 1986 Partnership. In the 1986 Partnership, virtually all partnership costs
and expenses other than property acquisition costs are allocated to the partners in the same percentages that partnership revenue is being shared at the time such expenses are incurred, with property acquisition costs and certain other expenses
being charged 85% to the accounts of the limited partners and 15% to the accounts of the general partners. Partnership revenue in the 1986 Partnership is allocated 85% to the limited partners’ accounts and 15% to the general partners’
accounts until program payout (as defined in the agreement of limited partnership for the 1986 Partnership). After program payout, the percentages of partnership revenue allocable to the respective accounts of the partners depend on the length of
the period during which program payout occurs and range from 60% to the limited partners’ accounts and 40% to the general partners’ accounts to 85% to the limited partners’ accounts and 15% to the general partners’ accounts.


  
 21 









 As co-general partners of any drilling or income programs that may be formed by UNIT and/or UPC during 2011
and participated in by the Partnership, UNIT and/or UPC and the Partnership will share the costs, expenses and revenues allocable to the general partners on a proportionate basis, 99% for the account of UNIT and/or UPC and 1% for the account of the
Partnership. The Partnership will not receive any portion of any management fees payable to the general partners nor any fees or payments for supervisory services which UNIT or UPC may render to such programs as operator of program wells or other
fees and payments which UNIT or UPC may be entitled to receive from such programs for services rendered to them or goods, materials, equipment or other property sold to them. 
 Extent and Nature of Operations. Although the General Partner maintains a general inventory of prospects, it cannot predict with certainty on which of those prospects wells will be
started during 2011 nor can it predict what producing properties, if any, will be acquired by it during 2011. Further, since the General Partner anticipates that the Partnership will acquire a small interest (either directly or through any drilling
or income programs of which it or UNIT serves as a general partner) in approximately 184 wells (however, the exact number of wells may vary greatly depending on the actual activity undertaken), it would be impractical to describe in any detail all
of the properties in which the Partnership can be expected to acquire some interest. 
 The Partnership’s drilling and development
operations are expected to include both Exploratory Wells and comparatively lower-risk Development Wells. Exploratory Wells include both the high-risk “wildcat” wells which are located in areas substantially removed from existing
production and “controlled” Exploratory Wells which are located in areas where production has been established and where objective horizons have produced from similar geological features in the vicinity. Based on UNIT’s historical
profile of its drilling operations, it is presently anticipated that the portion of the Aggregate Subscription expended for Partnership drilling operations (see “APPLICATION OF PROCEEDS”) will be spent approximately 7% on Exploratory Wells
and 93% on Development Wells. However, these percentages may vary significantly. 
 Certain of the Partnership’s Development Wells may be
drilled on prospects on which initial drilling operations were conducted by the General Partner or UNIT prior to the formation of the Partnership. Further, certain of the Partnership Wells will be drilled on prospects on which the General Partner,
UNIT or possibly future employee programs may conduct additional drilling operations in years subsequent to 2011. In either instance, the Partnership will have an interest only in those wells begun in 2011 and will have no rights in production from
wells commenced in years other than 2011 even though such other wells may be located on prospects or spacing units on which Partnership Wells have been drilled. Furthermore, it is possible that in years subsequent to 2011, UNIT, UPC or possibly
future employee programs will acquire additional interests in wells participated in by the Partnership. In such event the Partnership will generally not be entitled to share in the acquisition of such additional interests. With respect to the
acquisition of producing properties, UNIT will endeavor to diversify its investments by acquiring properties located in differing geographic locations and by balancing its investments between properties having high rates of production in early years
and properties with more consistent production over a longer term. See “CONFLICTS OF INTERESTS — Acquisition of Properties and Drilling Operations.” 
 Partnership Objectives 
 The Partnership is being formed to provide eligible
employees and directors the opportunity to participate in the oil and gas exploration and producing property acquisition activities of UNIT during 2011. UNIT hopes that participation in the Partnership will provide the participants with greater
proprietary interests in its operations and the potential for realizing a more direct benefit in the event these operations prove to be profitable. The Partnership has been structured to achieve the objective of providing the Limited Partners with
essentially the same economic returns that UNIT realizes from the wells drilled or acquired during 2011. 
 Areas of Interest

 The Agreement authorizes the Partnership to engage in oil and gas exploration, drilling and development operations and to acquire
producing oil and gas properties anywhere in the United States, but the areas presently under consideration are located in the states of Arkansas, Colorado, Kansas, Louisiana, Mississippi, Montana, New Mexico, North Dakota, Oklahoma, Pennsylvania,
Texas and Wyoming. It is possible that the Partnership may drill in inland waterways, riverbeds, bayous or marshes but no drilling in the open seas will be attempted. Plans to conduct drilling and development operations or to acquire producing
properties in certain of these states may be abandoned if attractive prospects cannot be obtained on satisfactory terms or if the Partnership is not fully subscribed. 

  
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 Transfer of Properties 
 In the case of wells drilled or producing properties acquired by the Partnership and UPC or UNIT for their own accounts and not through another drilling or income program, the Partnership will acquire
from UPC or UNIT a portion of the fractional undivided working interest in the properties or portions thereof comprising the spacing unit on which a proposed Partnership Well is to be drilled or on which a producing Partnership Well is located, and
UPC or UNIT will retain for its own account all or a portion of the remainder of such working interest. Such working interests will be sold to the Partnership for an amount equal to the Leasehold Acquisition Costs attributable to the interest being
acquired. Neither UNIT nor its affiliates will retain any overrides or other burdens on the working interests conveyed to the Partnership, and the respective working interests of UPC or UNIT and the Partnership in a property will bear their
proportionate shares of costs and revenues. 
 The Partnership’s direct interest in a property will only encompass the area included within
the spacing unit on which a Partnership Well is to be drilled or on which a producing Partnership Well is located, and, in the case of a Partnership Well to be drilled, it will acquire that interest only when the drilling of the well is ready to
commence. If the size of a spacing unit is ever reduced, or any subsequent well in which the Partnership has no interest is drilled thereon, the Partnership will have no interest in any additional wells drilled on properties which were part of the
original spacing unit unless such additional wells are commenced during 2011. If additional interests in Partnership Wells are acquired in years subsequent to 2011, the Partnership will generally not be entitled to participate or share in the
acquisition of such additional interests. In addition, if the Partnership Well drilled on a spacing unit is dry or abandoned, the Partnership will not have an interest in any subsequent or additional well drilled on the spacing unit unless it is
commenced during 2011. The Partnership will never own any significant amounts of undeveloped properties or have an occasion to sell or farm out any undeveloped Partnership Properties. 
 Transfers of properties to any drilling or income programs of which the Partnership serves as a general partner will be governed by the provisions of the agreement of limited partnership in effect with
respect thereto. If any such program is to be offered publicly, those provisions will have to be consistent with the provisions contained in the Guidelines for the Registration of Oil and Gas Programs adopted by the North American Securities
Administrators Association, Inc. 
 Record Title to Partnership Properties 

Record title to the Partnership Properties will be held by the General Partner. However, the General Partner will hold the Partnership Properties as a
nominee for the Partnership under a form of nominee agreement to be entered into between the General Partner and the Partnership. Under the form of nominee agreement, the General Partner will disclaim any beneficial interest in the Partnership
Properties held as nominee for the Partnership. 
 Marketing of Reserves 
 The General Partner has the authority to market the oil and gas production of the Partnership. In this connection, it may execute on behalf of the Partnership division orders, contracts for the marketing
or sale of oil, gas or other hydrocarbons or other marketing agreements. Sales of the oil and gas production of the Partnership will be to independent third parties or to the General Partner or its affiliates (see “CONFLICTS OF INTEREST”).

 Conduct of Operations 

The General Partner will have full, exclusive and complete discretion and control over the management, business and affairs of the Partnership and will
make all decisions affecting the Partnership Properties. To the extent that Partnership funds are reasonably available, the General Partner will cause the Partnership to (1) test and investigate the Partnership Properties by appropriate
geological and geophysical means, (2) conduct drilling and development operations on such Partnership Properties as it deems appropriate in view of such testing and investigation, (3) attempt completion of wells so drilled if in its
opinion conditions warrant the attempt and (4) properly equip and complete productive Partnership Wells. The General Partner will also cause the Partnership’s productive wells to be operated in accordance with sound and economical oil and
gas recovery practices. 

  
 23 









 The General Partner will operate certain drilling and productive wells on behalf of the Partnership in
accordance with the terms of the Agreement (see “COMPENSATION”). In those cases, execution of separate operating agreements will not be necessary unless third party owners are involved, e.g., fractional undivided interest Partnership
Properties and Partnership Properties that are pooled or unitized with other properties owned by third parties. In such cases, and in all cases where Partnership Properties are operated by third parties, the General Partner will, where appropriate,
make or cause to be made and enter into operating agreements, pooling agreements, unitization agreements, etc., in the form in general use in the area where the affected property is located. The General Partner is also authorized to execute
production sales contracts on behalf of the Partnership. 
 APPLICATION OF PROCEEDS 

The Aggregate Subscription will be used to pay costs and expenses incurred in the operations of the Partnership which are chargeable to the Limited
Partners. The organizational costs of the Partnership and the offering costs of the Units will be paid by the General Partner. 
 If all 900
Units offered hereby are sold, the proceeds to the Partnership would be $900,000. If the minimum 50 Units are sold, the proceeds to the Partnership would be $50,000. The General Partner estimates that the gross proceeds will be expended as follows:

  

																	
	 	  	$900,000 Program	 	  	$50,000 Program	 
	 	  	Percent	 	 	Amount	 	  	Percent	 	 	Amount	 
	 Leasehold Acquisition Costs of Properties to Be Drilled
	  	 	5	% 	 	$	45,000	  	  	 	5	% 	 	$	2,500	  
	 Drilling Costs of Exploratory Wells
	  	 	5	% 	 	 	45,000	  	  	 	5	% 	 	 	2,500	  
	 Drilling Costs of Development Wells
	  	 	70	% 	 	 	630,000	  	  	 	70	% 	 	 	35,000	  
	 Leasehold Acquisition Costs of Productive Properties
	  	 	20	% 	 	 	180,000	  	  	 	20	% 	 	 	10,000	  
	 Total
	  	 	100	% 	 	$	900,000	  	  	 	100	% 	 	$	50,000	  

 The foregoing allocation between
Drilling Costs and Leasehold Acquisition Costs is solely an estimate and the actual percentages may vary materially from this estimate. Funds otherwise available for drilling Exploratory Wells will be reduced to the extent that such funds are used
in conducting development operations in which the Partnership participates. 
 Until Capital Contributions are invested in the
Partnership’s operations, they will be temporarily deposited, with or without interest, in one or more bank accounts of the Partnership or invested in short-term United States government securities, money market funds, bank certificates of
deposit or commercial paper rated as “A1” or “P1” as the General Partner deems advisable. Partnership funds other than Capital Contributions may be commingled with the funds of the General Partner or UNIT. 

PARTICIPATION IN COSTS AND REVENUES 
 All costs of organizing the Partnership and offering Units therein will be paid by the General Partner. All costs incurred in the offering and syndication of any drilling or income program formed by UPC
or UNIT and its affiliates during 2011 in which the Partnership participates as a co-general partner will also be paid by the General Partner. All other Partnership costs and expenses will be charged 99% to the Limited Partners and 1% to the General
Partner until such time as the Aggregate Subscription has been fully expended. Thereafter and until the General Partner’s Minimum Capital Contribution has been fully expended, all of such costs and expenses will be


  
 24 









 
charged to the General Partner. After the General Partner’s Minimum Capital Contribution has been fully expended, such costs and expenses will be charged to the respective accounts of the
General Partner and the Limited Partners on the basis of their respective Percentages (see “GLOSSARY”). 
 All Partnership Revenues
will be allocated between the General Partner and the Limited Partners on the basis of their respective Percentages. 
 The General
Partner’s Minimum Capital Contribution will be determined as of December 31, 2011 and will be an amount equal to: 
  

	 	(a)	all costs and expenses previously charged to the General Partner as of that date, plus 


 

	 	(b)	the General Partner’s good faith estimate of the additional amounts that it will have to contribute in order to fund the Leasehold Acquisition Costs and Drilling
Costs expected to be incurred by the Partnership after that date. 

 The respective Percentages of the General Partner and the
Limited Partners will then be determined as of December 31, 2011 based on the relative contributions of the Partners previously made and expected to be made in the future during the remainder of the Partnership’s property acquisition and
drilling phases. See “GLOSSARY — General Partner’s Minimum Capital Contribution”, “General Partner’s Percentage” and “Limited Partners’ Percentage.” If the General Partner’s estimate of future
Leasehold Acquisition Costs and Drilling Costs proves to be lower than the actual amount of such costs and expenses, the excess amounts will be charged to the Partners on the basis of their respective Percentages and the Limited Partners’ share
will be paid out of their share of Partnership Revenues, Additional Assessments required of them or the proceeds of Partnership borrowings. See “ADDITIONAL FINANCING.” If the General Partner’s estimate of such costs and expenses
proves to be higher than the actual costs and expenses, the General Partner will continue to bear Partnership costs and expenses that would otherwise have been chargeable to the Limited Partners until the total Partnership costs and expenses charged
to it (including, without limitation, offering and organizational costs, Operating Expenses, general and administrative overhead costs and reimbursements and Special Production and Marketing Costs as well as Leasehold Acquisition Costs and Drilling
Costs) since the formation of the Partnership equals the General Partner’s Minimum Capital Contribution. In addition to actual contributions of cash or properties, any Partner will be deemed to have contributed amounts of Partnership Revenues
allocated to it which are used to pay its share of Partnership costs and expenses. 
 The following table presents a summary of the allocation
of Partnership costs, expenses and revenues between the General Partner and the Limited Partners: 
  

									
	 	  	General Partner	 	 	Limited Partners	 
	 COSTS AND EXPENSES
	  				 			
			
	 •      Organizational and offering costs of the Partnership and any drilling or income
programs in which the Partnership participates as a co-general partner
	  	 	100	% 	 	 	0	% 
			
	 •      All other Partnership Costs and Expenses:
	  				 			
			
	 •      Prior to time Limited Partner Capital Contributions are Entirely
expended
	  	 	1	% 	 	 	99	% 
			
	 •      After expenditure of Limited Partner Capital Contributions and until expenditure of
General Partner’s Minimum Capital Contribution
	  	 	100	% 	 	 	0	% 
			
	 •      After expenditure of General Partner’s Minimum Capital
Contribution
	  	 
  
	General Partner’s

Percentage
	  
   
	 	 
  
	Limited Partners’

Percentage
	  
   

			
	 REVENUES
	  	 
  
	General Partner’s

Percentage
	  
   
	 	 
  
	Limited Partners’

Percentage
	  
   



  
 25 









 COMPENSATION 
 Supervision of Operations 
 It is anticipated that the General Partner will operate
many of the Partnership Properties during the drilling and production of Partnership Wells. For the General Partner’s services performed as operator, the Partnership will compensate the General Partner its pro rata portion of the compensation
due to the General Partner under the operating agreements, if any, in effect with respect to such wells or, if none is in effect for such wells, at rates no higher than those normally charged in the same or a comparable geographic area by
non-affiliated persons or companies dealing at arm’s length. 
 That portion of the General Partner’s general and administrative
overhead expense that is attributable to its conduct of the actual and necessary business, affairs and operations of the Partnership will be reimbursed by the Partnership out of Partnership Revenue. The General Partner’s general and
administrative overhead expenses are determined in accordance with industry practices. The costs and expenses to be allocated include all customary and routine legal, accounting, geological, engineering, travel, office rent, telephone, secretarial,
salaries, data processing, word processing and other incidental reasonable expenses necessary to the conduct of the Partnership’s business and generated by the General Partner or allocated to it by UNIT, but will not include filing fees,
commissions, professional fees, printing costs and other expenses incurred in forming the Partnership or offering interests therein. The amount of such costs and expenses to be reimbursed with respect to any particular period will be determined by
allocating to the Partnership that portion of the General Partner’s total general and administrative overhead expense incurred during such period which is equal to the ratio of the Partnership’s total expenditures compared to the total
expenditures by the General Partner for its own account. The portion of such general and administrative overhead expense reimbursement which is charged to the Limited Partners may not exceed an amount equal to 3% of the Aggregate Subscription during
the first 12 months of the Partnership’s operations, and in each succeeding twelve-month period, the lesser of (a) 2% of the Aggregate Subscription and (b) 10% of the total Partnership Revenue realized in such twelve-month period.
Administrative expenses incurred directly by the Partnership, or incurred by the General Partner on behalf of the Partnership and reimbursable to the General Partner, such as legal, accounting, auditing, reporting, engineering, mailing and other
such fees, costs and expenses are not considered a part of the general and administrative expense reimbursed to the General Partner and the amounts thereof will not be subject to the limitations described in the preceding sentence. 

Purchase of Equipment and Provision of Services 
 UNIT, through its subsidiary Unit Drilling Company, will probably perform significant drilling services for the Partnership. UNIT also owns Superior Pipeline Company, L.L.C., an Oklahoma limited liability
company, which may build or own an interest in certain gathering systems through which a portion of the Partnership’s gas production is transported. 
 These persons are in the business of supplying such equipment and services to non-affiliated parties in the industry and any such equipment and such services will be acquired or provided at prices or
rates no higher than those normally charged in the same or comparable geographic area by non-affiliated persons or companies dealing at arms’ length. Production purchased by any affiliate of UNIT will be for prices which are not less than the
highest posted price (in the case of crude oil) or prevailing price (in the case of natural gas) in the same field or area. UNIT or one of its affiliates may provide other goods or services to the Partnership in which event the compensation received
therefore will be subject to the same restrictions and conditions described above and under “CONFLICTS OF INTEREST” below. 

  
 26 









 Prior Programs 
 UNIT was formed in 1986 in connection with a major reorganization and recapitalization whereby UNIT acquired all of the assets and liabilities of all of the limited partnerships formed by UNIT’s
predecessor, Unit Drilling and Exploration Company (“UDEC”), during the period of 1980 through 1983 in exchange for shares of UNIT’s common stock and UDEC was merged with a wholly owned subsidiary of UNIT whereby UDEC was the
surviving corporation and thereby became a wholly owned subsidiary of UNIT. UNIT has conducted one oil and gas program since the date of its formation, the 1986 Energy Program. The 1986 Energy Program was formed on June 12, 1987 with total
subscriptions of one million dollars. The Unit 1986 Employee Oil and Gas Limited Partnership is a co-general partner with UPC of the 1986 Energy Program. Direct compensation charged to or paid by the partnerships and earned by the General Partners
for their services in connection with these programs through September 30, 2010, is set forth below. 
  

																	
	 Program
	  	Management
Fee(1)	 	 	Compensation for
Supervision
and
Operation of
Productive
and
Drilling
Wells(2)(3)	 	  	Reimbursement
of General
Administrative
and Overhead
Expense(2)(3)(4)	 	  	Fees
Received as
a Drilling
Contractor(2)	 
	
1979(***)

	  	 	150,000	  	 	 	2,833,720	  	  	 	2,539,915	  	  	 	1,835,762	  
	 1980
	  	 	200,000	  	 	 	261,456	  	  	 	1,345,158	  	  	 	1,810,310	  
	 1981
	  	 	1,250,000	(5) 	 	 	329,695	  	  	 	1,892,568	  	  	 	4,047,260	  
	 1981-II
	  	 	450,000	  	 	 	158,406	  	  	 	1,607,706	  	  	 	1,629,201	  
	 1982-A
	  	 	634,200	  	 	 	521,910	  	  	 	1,688,024	  	  	 	4,110,107	  
	 1982-B
	  	 	316,650	  	 	 	331,594	  	  	 	1,224,023	  	  	 	4,945,437	  
	 1983-A
	  	 	50,600	  	 	 	151,289	  	  	 	698,597	  	  	 	695,255	  
	 1984
	  	 	—  	  	 	 	376,310	  	  	 	1,728,951	  	  	 	829,503	  
	 1984 Employee(*)
	  	 	—  	  	 	 	3,924	  	  	 	5,000	  	  	 	13,452	  
	 1985 Employee(*)
	  	 	—  	  	 	 	10,316	  	  	 	—  	  	  	 	54,892	  
	 1986 Energy Income Fund(**)
	  	 	—  	  	 	 	451,739	  	  	 	3,130,851	  	  	 	109,383	  
	 1986 Employee(*)
	  	 	—  	  	 	 	23,505	  	  	 	—  	  	  	 	59,446	  
	 1987 Employee(*)
	  	 	—  	  	 	 	50,688	  	  	 	—  	  	  	 	97,079	  
	 1988 Employee(*)
	  	 	—  	  	 	 	93,854	  	  	 	—  	  	  	 	112,861	  
	 1989 Employee(*)
	  	 	—  	  	 	 	54,536	  	  	 	—  	  	  	 	165,436	  
	 1990 Employee(*)
	  	 	—  	  	 	 	28,884	  	  	 	—  	  	  	 	144,722	  
	 1991 Employee(****)
	  	 	—  	  	 	 	572,357	  	  	 	—  	  	  	 	144,993	  
	 1992 Employee(****)
	  	 	—  	  	 	 	159,914	  	  	 	—  	  	  	 	14,934	  
	 1993 Employee(****)
	  	 	—  	  	 	 	85,790	  	  	 	—  	  	  	 	68,504	  
	 1994 Employee(****)
	  	 	—  	  	 	 	122,392	  	  	 	—  	  	  	 	42,135	  
	 1995 Employee(****)
	  	 	—  	  	 	 	72,331	  	  	 	—  	  	  	 	35,903	  
	 1996 Employee(****)
	  	 	—  	  	 	 	85,199	  	  	 	—  	  	  	 	112,911	  
	 1997 Employee(****)
	  	 	—  	  	 	 	75,475	  	  	 	—  	  	  	 	170,174	  
	 1998 Employee(****)
	  	 	—  	  	 	 	57,689	  	  	 	—  	  	  	 	161,343	  
	 1999 Employee(****)
	  	 	—  	  	 	 	95,782	  	  	 	—  	  	  	 	186,408	  
	 Consolidated Program(*)(****)
	  	 	—  	  	 	 	696,049	  	  	 	—  	  	  	 	1,116	  
	 2000 Employee
	  	 	—  	  	 	 	206,988	  	  	 	—  	  	  	 	405,391	  
	 2001 Employee
	  	 	—  	  	 	 	62,545	  	  	 	—  	  	  	 	336,969	  
	 2002 Employee
	  	 	—  	  	 	 	66,362	  	  	 	—  	  	  	 	258,671	  
	 2003 Employee
	  	 	—  	  	 	 	78,537	  	  	 	—  	  	  	 	437,473	  
	 2004 Employee
	  	 	—  	  	 	 	28,053	  	  	 	—  	  	  	 	228,343	  
	 2005 Employee
	  	 	—  	  	 	 	64,961	  	  	 	—  	  	  	 	428,134	  
	 2006 Employee
	  	 	—  	  	 	 	37,621	  	  	 	—  	  	  	 	670,401	  
	 2007 Employee
	  	 	—  	  	 	 	23,683	  	  	 	—  	  	  	 	718,647	  
	 2008 Employee
	  	 	—  	  	 	 	23,282	  	  	 	—  	  	  	 	911,506	  
	 2009 Employee
	  	 	—  	  	 	 	3,239	  	  	 	—  	  	  	 	271,646	  
	 2010 Employee
	  	 	—  	  	 	 	1,401	  	  	 	—  	  	  	 	266,439	  

  

	(*)	 Effective December 31, 1993, pursuant to an Agreement and Plan of Merger, this employee partnership was merged with and into the Unit Consolidated
Employee Oil and Gas Limited Partnership (the “Consolidated Program”), with the latter being the surviving limited partnership. See Prior Activities. 



  
 27 










	(**)	 Formed primarily for purposes of acquiring producing oil and gas properties. 



	(***)	 Effective July 1, 2003 this program was dissolved. 



	(****)	 Effective December 31, 2002, pursuant to an Agreement and Plan of Merger, this employee partnership was merged with and into the Unit Consolidated
Employee Oil and Gas Limited Partnership (the “Consolidated Program”), with the latter being the surviving limited partnership. See Prior Activities. 



	(1)	Paid to both UDEC and a prior Key Employee Exploration Fund as general partners. No management fee was payable to UDEC or any of its affiliates by any of the 1984 -
2010 Employee Programs and no management fee is payable by the Partnership to UNIT or any of its affiliates. 


	(2)	Paid only to UDEC. 


	(3)	In the case of compensation for supervision and operation of productive wells and reimbursement of UNIT’s general and administrative overhead expense, the general
partners generally were charged with and paid a percentage of such amounts equal to the percentage of partnership revenues being allocated to them. 


	(4)	Although the partnership agreement for each of the 1985 - 2010 Employee Programs provides that the General Partner is entitled to reimbursement for the general
administrative and overhead expenses attributable to each of such programs, the General Partner has to date elected not to seek such reimbursement. However, there can be no assurance that the General Partner will continue to forego such
reimbursement in the future. 


	(5)	Includes a special allocation of gross revenues totaling $500,000. 

 MANAGEMENT 
 The General Partner 

UNIT was formed in 1986 in connection with a major reorganization and recapitalization whereby UNIT acquired all of the assets and liabilities of all of
the limited partnerships formed by UNIT’s predecessor, UDEC, in exchange for shares of UNIT’s common stock in a transaction whereby UDEC became a wholly owned subsidiary of UNIT. UPC was incorporated in the State of Oklahoma on
February 9, 1984 as Sunshine Development Corporation (“SDC”) and was acquired by UDEC in 1985. The name was changed to Unit Petroleum Company in 1988. On October 8, 1985 pursuant to the terms of a Stock Purchase Agreement,”
UDEC purchased all of the issued and outstanding stock of SDC whereby SDC became a wholly owned subsidiary of UDEC. On February 1, 1988, pursuant to the terms of an “Amended and Restated Certificate of Incorporation”, SDC was renamed
Unit Petroleum Company. 
 UPC’s as well as UNIT’s, principal office is at 7130 South Lewis Avenue, Suite 1000, Tulsa, Oklahoma 74136
and its telephone number is (918) 493-7700. UNIT through its various subsidiaries is engaged in the onshore contract drilling of oil and gas wells, the exploration for and production of oil and gas and the gathering and transportation of
natural gas. Unless the context otherwise requires, references in this Memorandum to UNIT include its predecessor as well as all or any of its subsidiaries. 

  
 28 









 Officers, Directors and Key Employees 
 The Partnership will have no directors or officers. The directors of the General Partner are elected annually and serve until their successors are elected and qualified. Directors of UNIT are elected at
the Annual Meeting of Shareholders for a staggered term of three years each, or until their successors are duly elected and qualified. The executive officers of the General Partner are elected by and serve at the pleasure of its Board of Directors.
The names, ages and respective positions of the directors and executive officers of UNIT are as follows: 
  

							
	 Name
	    	Age	 	    	 Position

	 King P. Kirchner
	    	 	83	  	    	Director
			
	 John G. Nikkel
	    	 	75	  	    	Chairman of the Board
			
	 Larry D. Pinkston
	    	 	56	  	    	President, Chief Executive Officer and Director
			
	 Mark E. Schell
	    	 	53	  	    	Senior Vice President, Secretary and General Counsel
			
	 David T. Merrill
	    	 	49	  	    	Treasurer and Chief Financial Officer
			
	 William B. Morgan
	    	 	66	  	    	Director
			
	 John H. Williams
	    	 	92	  	    	Director
			
	 J. Michael Adcock
	    	 	61	  	    	Director
			
	 Gary R. Christopher
	    	 	61	  	    	Director
			
	 Robert J. Sullivan, Jr.
	    	 	65	  	    	Director
			
	 Steven B. Hildebrand
	    	 	56	  	    	Director
	
	The names, ages and respective positions of the directors and executive officers of UPC are as follows:
			
	 Name
	    	Age	 	    	 Position

	 Larry D. Pinkston
	    	 	56	  	    	President and Director
			
	 Mark E. Schell
	    	 	53	  	    	Senior Vice President, Secretary and General Counsel and Director
			
	 Bradford J. Guidry
	    	 	55	  	    	Executive Vice President
			
	 David T. Merrill
	    	 	49	  	    	Treasurer and Chief Financial Officer

 Mr. Kirchner,
a co-founder of UNIT, has been a director since 1963. He served as UNIT’s President until November, 1983, as its Chief Executive Officer until June 30, 2001, and served as the Chairman of the Board until July 31, 2003.
Mr. Kirchner is a Registered Professional Engineer within the State of Oklahoma, having received degrees in Mechanical Engineering from Oklahoma State University and in Petroleum Engineering, with honors, from the University of Oklahoma.
Following graduation, he was employed by Lufkin Manufacturing as a development engineer for hydraulic pumping units. Prior to co-founding UNIT, he served in the U.S. Army during the Korean War and after that as vice-president of engineering and
operations for Woolaroc Oil Company. Mr. Kirchner is a 2006 inductee into both the Oklahoma Hall of Fame and the University of Tulsa, Collins College of Business Hall of Fame. 
 Mr. Nikkel joined UNIT as its President, Chief Operating Officer and a director in 1983. He was elected its Chief Executive Officer in July, 2001 and Chairman of the Board in August, 2003.
Mr. Nikkel retired as an employee and as the Chief Executive Officer of UNIT on April 1, 2005. He currently holds the position of Chairman of the Board. From 1976 until January, 1982 when he co-founded Nike Exploration Company,
Mr. Nikkel was an officer and director of Cotton Petroleum Corporation, serving as the President of Cotton from 1979 until his departure. Before joining Cotton, Mr. Nikkel was employed by Amoco Production Company for 18 years, last serving
as Division Geologist for Amoco’s Denver Division. Mr. Nikkel presently serves as President and a director of Nike Exploration Company, a family owned oil and gas investment company. Mr. Nikkel received a Bachelor of Science degree in
Geology and Mathematics from Texas Christian University. 
 Mr. Pinkston joined UNIT in December, 1981. He had served as Corporate Budget
Director and Assistant Controller before being appointed Controller in February, 1985. In December, 1986, he was elected Treasurer and was elected to the position of Vice President and Chief Financial Officer in May, 1989. In August, 2003, he was
elected to the position of President. He was elected a director by the Board in January, 2004. In February, 2004, in 

  
 29 









 
addition to his position as President, he was elected to the office of Chief Operating Officer. Effective April 1, 2005, Mr. Pinkston was elected to the additional position of Chief
Executive Officer. He holds a Bachelor of Science Degree in Accounting from East Central University of Oklahoma and is a Certified Public Accountant. 
 Mr. Schell joined UNIT in January, 1987, as its Secretary and General Counsel. In December, 2002, he was elected to the additional position of Senior Vice President. From 1979 until joining UNIT,
Mr. Schell was Counsel, Vice President and a member of the Board of Directors of C&S Exploration, Inc. He received a Bachelor of Science degree in Political Science from Arizona State University and his Juris Doctorate degree from the
University of Tulsa Law School. He is a member of the Oklahoma and American Bar Association as well as being a member of the American Corporate Counsel Association. 
 Mr. Merrill joined UNIT in August, 2003 as Vice President, Finance. From May, 1999 through August, 2003, Mr. Merrill served as Senior Vice President, Finance with TV Guide Networks, Inc. From
July, 1996 through May, 1999 he was a Senior Manager with Deloitte & Touche LLP. From July, 1994 through July, 1996 he was Director of Financial Reporting and Special Projects for MAPCO, Inc. He began his career as an auditor with Deloitte,
Haskins & Sells in 1983. Mr. Merrill received a Bachelor of Business Administration Degree in Accounting from the University of Oklahoma and is a Certified Public Accountant. In February, 2004 he was elected to the position of
Treasurer and Chief Financial Officer. 
 Mr. Morgan was elected a director of UNIT in 1988. Mr. Morgan retired in June 2007 from his
position as Executive Vice President and General Counsel of St. John Health System, Inc., Tulsa, Oklahoma, and President of its principal for-profit subsidiary Utica Services, Inc., which positions he had held since 1995. Prior to joining St. John,
he was a Partner in the law firm of Doerner, Saunders, Daniel & Anderson, Tulsa, Oklahoma, and served as Adjunct Professor of Law at the University of Tulsa College of Law, where he taught Securities Regulation. During 1968 and 1969, he
served as a United States Army Officer in Vietnam and was awarded several medals including the Bronze Star. Mr. Morgan has an undergraduate degree from Muhlenberg College, Allentown, Pennsylvania and a Juris Doctor from the University of Tulsa
College of Law. Mr. Morgan is a member of numerous professional and Bar associations and various federal Bars including the United States Supreme Court. He has been listed in Who’s Who in American Law, Who’s Who in American
Education and The Best Lawyers in America. Mr. Morgan is a Fellow of the American College of Healthcare Executives. 

Mr. Williams was elected a director of UNIT in December, 1988. Mr. Williams is engaged in personal investments and has been for more than five
years. He was Chairman of the Board and Chief Executive Officer of The Williams Companies, Inc. before retiring in 1978 and continues to serve as an honorary director. Mr. Williams is a director of Apco Argentina, Inc. and also an honorary
director of Willbros Group, Inc. He formerly served as a director of Petrolera Entre Lomas S.A. In addition, Mr. Williams is a member of the Tulsa Performing Arts Center Trust. Mr. Williams was a 1977 inductee into the Oklahoma Hall of
Fame, and a 2006 inductee into the University of Tulsa, Collins College of Business Hall of Fame. 
 Mr. Adcock was elected a director in
December, 1997. He is an attorney and is currently a Co-trustee of the Don Bodard Trust, which is a private business trust that deals in real estate, oil and natural gas properties and other equity investments. He is Chairman of the Board of Arvest
Bank, Shawnee, and a director of Community Health Partners, Inc. and Midwest Consolidated Plastics, LLC. Between 1997 and September, 1998 he was the Chairman of the Board of Ameribank and President and Chief Executive Officer of American National
Bank and Trust Company of Shawnee, Oklahoma, and Chairman of AmeriTrust Corporation, Tulsa, Oklahoma. Prior to holding these positions, he was engaged in the private practice of law and served as General Counsel for Ameribank Corporation.

 Mr. Gary R. Christopher is engaged in personal investments and consulting. Between August, 1999 and January, 2004, he served as
President and Chief Executive Officer of PetroCorp Incorporated (a public oil and gas exploration company), and from March 1996 to August 1999 he served as the Acquisition Coordinator of Kaiser-Francis Oil Company. His other past professional
experience includes serving as Vice President of Acquisitions for Indian Wells Oil Company, Senior Vice President and Manager of the Energy Lending Division of First National Bank of Tulsa and from 1991 to 1996 Senior Vice President and Manager of
Energy Lending for Bank of Oklahoma. Previous to that, Mr. Christopher worked for Amerada Hess Corporation as a Reservoir Engineer and for Texaco, Inc. as a Production Engineer. Mr. Christopher is a member of the Society of Petroleum
Engineers, Society of Petroleum Evaluation Engineers, and the Oklahoma Independent Petroleum Association. 

  
 30 









 
Mr. Christopher received a B.S. degree in Petroleum Engineering from the University of Missouri at Rolla. Mr. Christopher is a past Director of the Petroleum Club of Tulsa, Middle Bay
Oil Company, Three Tech Energy, PetroCorp Incorporated and a present Director of the Summit Bank of Oklahoma. 
 Mr. Robert J.
Sullivan Jr. is a Principal with Sullivan and Company LLC, a family-owned independent oil and gas exploration and production company founded in 1958. He is also the Founder (1989) and served as Chairman and Chief Executive Officer of Lumen
Energy Corporation prior to its sale in 2004. Mr. Sullivan was appointed to Oklahoma Governor Frank Keating’s Cabinet as Secretary of Energy in March, 2002. He received a BBA from the University of Notre Dame, and a MBA from the University
of Michigan. Mr. Sullivan is a Board Member of the Oklahoma Independent Petroleum Association, St. John Medical Center, St. Joseph Residence, and former Board Member of University of Notre Dame Alumni Association, Catholic Charities and
Gatesway Foundation. He also is Trustee for the Monte Cassino Endowment Trust, a Member of the University of Notre Dame Irish Studies Advisory Council and Past Chairman of the following School Boards: Cascia Hall Preparatory School; Monte Cassino
School and School of St. Mary. 
 Mr. Hildebrand was elected as a director in October 2008. Mr. Hildebrand retired in March 2008 from
a twenty-one year tenure at Dollar Thrifty Automotive Group (NYSE: DTG), a car rental company, and its subsidiaries. Mr. Hildebrand was the Chief Financial Officer during his last ten years with Dollar Thrifty Automotive Group and before that
served as Executive Vice President and Chief Financial Officer of Thrifty Rent-A-Car System, Inc., a subsidiary of Dollar Thrifty. Before joining Dollar Thrifty, Mr. Hildebrand served in several positions for Franklin Supply Company from 1980
to 1987 including Controller and Vice President of Finance. From 1976 to 1980, Mr. Hildebrand was with the public accounting firm Coopers & Lybrand, most recently as Audit Supervisor. Mr. Hildebrand has been designated by the
board of directors as an audit committee financial expert. 
 Prior Employee Programs 

Since 1984, UNIT has formed limited partnerships for investment by certain of its key employees and directors that participate with UNIT in its
exploration and production operations. The name, month of formation and amount of limited partner capital subscriptions of each of these limited partnerships (the “Employee Programs”) are set forth below. 

 

							
	 Name
	  	Formed	  	Limited
Partners’
Capital
Subscriptions
	 
	 Unit 1984 Employee Oil and Gas Program
	  	April 1984	  	$	348,000	  
	 Unit 1985 Employee Oil and Gas Limited Partnership
	  	January 1985	  	$	378,000	  
	 Unit 1986 Employee Oil and Gas Limited Partnership
	  	January 1986	  	$	307,000	  
	 Unit 1987 Employee Oil and Gas Limited Partnership
	  	March 1987	  	$	209,000	  
	 Unit 1988 Employee Oil and Gas Limited Partnership
	  	April 29, 1988	  	$	177,000	  
	 Unit 1989 Employee Oil and Gas Limited Partnership
	  	December 30, 1988	  	$	157,000	  
	 Unit 1990 Employee Oil and Gas Limited Partnership
	  	January 19, 1990	  	$	253,000	  
	 Unit 1991 Employee Oil and Gas Limited Partnership
	  	January 7, 1991	  	$	263,000	  
	 Unit 1992 Employee Oil and Gas Limited Partnership
	  	January 23, 1992	  	$	240,000	  
	 Unit 1993 Employee Oil and Gas Limited Partnership
	  	January 21, 1993	  	$	245,000	  
	 Unit 1994 Employee Oil and Gas Limited Partnership
	  	January 19, 1994	  	$	284,000	  
	 Unit 1995 Employee Oil and Gas Limited Partnership
	  	March 7, 1995	  	$	454,000	  
	 Unit 1996 Employee Oil and Gas Limited Partnership
	  	February 5, 1996	  	$	437,000	  
	 Unit 1997 Employee Oil and Gas Limited Partnership
	  	February 4, 1997	  	$	413,000	  
	 Unit 1998 Employee Oil and Gas Limited Partnership
	  	February 19, 1998	  	$	471,000	  
	 Unit 1999 Employee Oil and Gas Limited Partnership
	  	February 22, 1999	  	$	188,000	  
	 Unit 2000 Employee Oil and Gas Limited Partnership
	  	February 22, 2000	  	$	199,000	  
	 Unit 2001 Employee Oil and Gas Limited Partnership
	  	February 9, 2001	  	$	370,000	  
	 Unit 2002 Employee Oil and Gas Limited Partnership
	  	January 30, 2002	  	$	457,000	  
	 Unit 2003 Employee Oil and Gas Limited Partnership
	  	January 31, 2003	  	$	284,000	  
	 Unit 2004 Employee Oil and Gas Limited Partnership
	  	February 18, 2004	  	$	434,000	  
	 Unit 2005 Employee Oil and Gas Limited Partnership
	  	January 26, 2005	  	$	496,000	  
	 Unit 2006 Employee Oil and Gas Limited Partnership
	  	February 2, 2006	  	$	767,000	  
	 Unit 2007 Employee Oil and Gas Limited Partnership
	  	February 6, 2007	  	$	946,000	  
	 Unit 2008 Employee Oil and Gas Limited Partnership
	  	January 31, 2008	  	$	841,000	  
	 Unit 2009 Employee Oil and Gas Limited Partnership
	  	February 5, 2009	  	$	391,000	  
	 Unit 2010 Employee Oil and Gas Limited Partnership
	  	December 31, 2009	  	$	485,000	  


  
 31 









 One-half of the capital subscriptions from all limited partners were required to be paid in the 1984
Employee Program, three-fourths of the capital subscriptions from all limited partners were required to be paid in the 1985 Employee Program and the 1986 Employee Program. All of the capital subscriptions from all limited partners, including those
shown below, were required to be paid in the 1987 through 2010 Employee Programs. The capital subscriptions of the following limited partners to the 2008, 2009 and 2010 Employee Programs were as shown below: 

 

															
	 Subscriber
	  	Position with
UNIT	    	Amount of
Capital
Subscription	 
	  	    	2008	 	    	2009	 	    	2010	 
	 King P. Kirchner(1)
	  	Director	    	$	100,000	  	    	$	100,000	  	    	$	150,000	  
					
	 John G. Nikkel
	  	Chairman of the Board	    	$	250,000	  	    	 	0	  	    	 	0	  
					
	 Larry D. Pinkston
	  	President & Director	    	$	20,000	  	    	$	4,000	  	    	$	12,000	  
					
	 J. Michael Adcock
	  	Director	    	 	86,000	  	    	 	100,000	  	    	 	113,000	  
					
	 Gary R. Christopher
	  	Director	    	 	100,000	  	    	 	40,000	  	    	 	50,000	  

  

	(1)	Mr. Kirchner invested in these programs through the King P. Kirchner Revocable Trust as permitted by the limited partnership agreement of those Employee Programs.


 Ownership of Common Stock 
 UNIT’s Common Stock is listed on the New York Stock Exchange as reported on the Composite Tape. On December 30, 2010 there were 47,910,431 shares outstanding. 

As of December 30, 2010, the directors and officers of UNIT owned of record or beneficially owned shares of UNIT Common Stock as follows:

  

									
	 Name
	  	Amount of
Beneficial
Ownership(1)	 	 	% of 
Outstanding(1)	 
	 King P. Kirchner
	  	 	166,320	  	 	 	*	  
	 John H. Williams
	  	 	36,000	  	 	 	*	  
	 John G. Nikkel
	  	 	153,989	  	 	 	*	  
	 Larry D. Pinkston
	  	 	190,823	  	 	 	*	  
	 Mark E. Schell
	  	 	122,712	  	 	 	*	  
	 William B. Morgan
	  	 	39,000	  	 	 	*	  
	 J. Michael Adcock
	  	 	38,891	  	 	 	*	  
	 Gary R. Christopher
	  	 	23,500	  	 	 	*	  
	 Robert J. Sullivan, Jr.
	  	 	17,500	  	 	 	*	  
	 David T. Merrill
	  	 	60,180	  	 	 	*	  
	 Steven B. Hildebrand
	  	 	9,000	  	 	 	*	  
	 All Officers and Directors as a Group
	  	 	857,915	(2)(3)(4)(5)(6)(7) 	 	 	1.77	% 

  

	*	Less than 1% 


  
 32 










	(1)	The number of shares includes the shares presently issued and outstanding plus the number of shares which any owner has the right to acquire within 60 days after
December 30, 2010. For purposes of calculating the percent of the shares outstanding held by each owner, the total number of shares excludes the shares which all other persons have the right to acquire within 60 days after December 30,
2010 pursuant to the exercise of currently exercisable stock options. 


	(2)	Includes shares of common stock held under UNIT’s 401(k) thrift plan as of December 30, 2010 for the account of: David T. Merrill, 3,815; Larry D. Pinkston,
6,158; and Mark E. Schell, 35,327. 


	(3)	Includes unexercised stock options granted under UNIT’s Non-Employee Directors’ Stock Option Plan to each of the following, all of which are currently
exercisable at the discretion of the holder: J. Michael Adcock, 21,000; William B. Morgan, 31,500; John H. Williams, 35,000; John G. Nikkel, 21,000; Gary R. Christopher 17,500; Robert J. Sullivan, Jr. 17,500; Steven B. Hildebrand, 7,000, and King P.
Kirchner 17,500 shares and all Non-Employee Directors as a group, 168,000. 


	(4)	Includes unexercised stock options granted under UNIT’s Amended and Restated Stock Option Plan to each of the following, all of which are exercisable within 60
days from December 30, 2010 at the discretion of the holder: David T. Merrill, 13,000; Larry D. Pinkston, 27,500; and Mark E. Schell, 23,500. 


	(5)	Of the shares shown, Mr. J. Michael Adcock is deemed to be the beneficial owner of 17,491 shares by virtue of his position as one of three trustees of the Don
Bodard 1995 Revocable Trust. 


	(6)	Includes the following shares of stock appreciation rights granted to each of the following which are exercisable within 60 days from December 30, 2010 at the
discretion of the holder: David T. Merrill, 21,772; Larry D. Pinkston, 71,245; and Mark E. Schell, 23,949. 


	(7)	Of the shares listed as being beneficially owned, the following individuals disclaim any beneficial interest in shares held by spouses or for the benefit of family
members: J. Michael Adcock, 400; and Steven B. Hildebrand, 2,000 and John G. Nikkel 35,000. 

 Interest of Management in
Certain Transactions 
 Reference is made to “COMPENSATION” for a discussion of the compensation for supervision and operation
of productive wells and the reimbursement of overhead expenses attributable to the Partnership’s operations to which UNIT is entitled under the terms of the Partnership Agreement. 

CONFLICTS OF INTEREST 

There will be situations in which the individual interests of the General Partner and the Limited Partners will conflict. Although the General Partner is
obligated to deal fairly and in good faith with the Limited Partners and conduct Partnership operations using the standards of a prudent operator in the oil and gas industry, such conflicts may not in every instance be resolved to the maximum
advantage of the Limited Partners. Certain circumstances which will or may involve potential conflicts of interest are as follows: 
  

	 	•	 	 The General Partner currently manages and in the future will sponsor and manage oil and natural gas drilling programs similar to the Partnership.



  

	 	•	 	 The General Partner will decide which prospects the Partnership will acquire. 



 

	 	•	 	 The General Partner will act as operator for Partnership Wells and will, through its affiliates, furnish drilling and/or marketing services with
respect to Partnership Wells, the terms of which have not been negotiated by non-affiliated persons. 


  

	 	•	 	 The General Partner is a general partner of numerous other partnerships, and owes duties of good faith dealing to such other partnerships.



  

	 	•	 	 The General Partner and its affiliates engage in drilling, operating and producing activities for other partnerships. 



  
 33 









 Acquisition of Properties and Drilling Operations 

With certain limited exceptions it is anticipated that the Partnership will participate in each producing property, if any, acquired by the General
Partner and in the drilling of each of the wells, if any, commenced by the General Partner for its own account during the period commencing January 1, 2011, or from the formation of the Partnership if subsequent to January 1, 2011, through
December 31, 2011 except for wells: 
  

	 	(i)	drilled outside the 48 contiguous United States; 

  

	 	(ii)	drilled as part of secondary or tertiary recovery operations which were in existence prior to formation of the Partnership; 


 

	 	(iii)	drilled by third parties under farm-out or similar arrangements with UNIT or the General Partner or whereby UNIT or the General Partner may be entitled to an overriding
royalty, reversionary or other similar interest in the production from such wells but is not obligated to pay any of the Drilling Costs thereof; 

  

	 	(iv)	acquired by UNIT or the General Partner through the acquisition by UNIT or the General Partner of, or merger of UNIT or the General Partner with, other companies; or


  

	 	(v)	with respect to which the General Partner does not believe that the potential economic return therefrom justifies the costs and participation by the Partnership.


 As a result, the Partnership may have an interest in wells located on prospects on which producing wells have been drilled by
UNIT or the General Partner in prior years. Likewise, it is possible that the Partnership will participate in the drilling of initial wells on prospects on which some or all of the development or offset wells will be drilled in years subsequent to
2011. In the latter case, the Partnership would have no right to participate in the drilling of such development or offset wells. 
 Sometimes
UNIT will agree to participate in drilling operations on a prospect which it may not believe are fully warranted from an economic standpoint if it believes that such participation is necessary for, or will significantly increase its chances of,
obtaining a contract to drill the well with one of its drilling rigs and the revenues from the contract make the economics of the entire arrangement desirable from UNIT’s standpoint. In such an instance, the Partnership would not be entitled to
any of the drilling contract revenues so the General Partner will not cause the Partnership to participate in such a well. However, an analysis of the economic potential of any proposed well is a very inexact science and wells which have a very high
potential commonly prove to be dry or only marginally profitable and occasionally a well with apparently very little promise may prove to be very profitable. Thus, there can be no assurance that the General Partner will always make the most
profitable decision from the Partnership’s standpoint in determining in which of such potential wells the Partnership should or should not participate. 
 Because the Partnership will acquire an interest only in those properties comprising the spacing unit on which each Partnership Well is located, it will not be entitled to participate in other wells
drilled by the General Partner, UNIT or any of its affiliates in the same prospect area unless the drilling of those wells commences during the period from January 1, 2011, or from the formation of the Partnership if subsequent to
January 1, 2011, through December 31, 2011. If the size of a spacing unit in which the Partnership has an interest is reduced, the Partnership will have no interest in any additional well drilled on the property comprising the original
spacing unit unless it is commenced during the period from January 1, 2011, or from the formation of the Partnership if subsequent to January 1, 2011, through December 31, 2011. Likewise the Partnership would have no interest in any
increased density wells drilled on the original spacing unit unless such wells were drilled during 2011. In addition, if additional interests are acquired in wells participated in by the Partnership after 2011, the Partnership will generally not be
entitled to participate in the acquisition of such additional interests. Management believes that the apparent conflicts of interest arising from these situations are mitigated by the fact that the Partnership is expected to participate in all of
UNIT’s drilling operations (with the exceptions noted above) conducted during the period. Thus, there is little opportunity for the General Partner to selectively choose Partnership drilling locations for the purpose of proving up other
properties of UNIT or its affiliates in which the Partnership has no interest. Further, the Partnership will benefit in many instances by its participation in the drilling of wells located on prospects previously proved up by drilling operations
conducted by UNIT prior to formation of the Partnership. 

  
 34 









 Participation in UNIT’s Drilling or Income Programs 

If UNIT forms any drilling or income programs in 2011, it is anticipated that the Partnership will serve as a co-general partner with UNIT in any such
drilling or income programs, or both. As the other co-general partner of any such drilling or income program, UNIT would have exclusive management and control over the business, operations and affairs of the drilling or income program. Conflicts of
interest may arise between the limited partners and the general partners of such drilling or income program and it is possible that UNIT may elect to resolve those conflicts in favor of the limited partners. Further, if any such drilling or income
program is offered publicly, the program agreement will be required to contain a number of provisions concerning the conduct of program operations and handling conflicts of interests required by the Guidelines for the Registration of Oil and Gas
Programs adopted by the North American Securities Administrators Association, Inc. Such provisions may significantly reduce the flexibility of UNIT in managing such programs or may affect the profitability of the program operations or the
transactions between the general partners and the program. 
 Transfer of Properties 

The General Partner or its affiliates are authorized to transfer interests in oil and gas properties to the Partnership, in which case the General Partner
or its affiliate will receive an amount equal to the Leasehold Acquisition Costs attributable to the interests being acquired by the Partnership in the spacing unit on which the Partnership Well is located or is to be drilled. The amount of the
Leasehold Acquisition Costs attributable to the fractional undivided interest in a property transferred to the Partnership by the General Partner or any affiliate shall not be reduced or offset by the amount of any gain or profit the General Partner
or its affiliate might have realized by any prior sale or transfer of a fractional undivided interest in the property to an unaffiliated third party for a price in excess of the portion of the Leasehold Acquisition Costs of the property that is
attributable to the transferred interest. The Partnership will not be reimbursed for or refunded any Leasehold Acquisition Costs if the size of a spacing unit on which a Partnership Well is located or drilled is reduced even though the Partnership
will have no interest in any subsequent wells drilled on the area encompassed by the original spacing unit unless they are commenced during 2011. 
 A sale, transfer or conveyance to the Partnership of less than all of the ownership of the General Partner or its affiliates in any interest or property is prohibited unless: 

 

	 	(1)	the interest retained by the General Partner or its affiliates is a proportionate working interest; 


 

	 	(2)	the obligations of the Partnership with respect to the properties will be substantially the same proportionately as those of the General Partner or its affiliates at
the time it acquired the properties; and 

  

	 	(3)	the Partnership’s interest in revenues will not be less than the proportionate interest therein of the General Partner or its affiliates when it acquired the
properties. 

 With respect to the General Partner or its affiliates’ remaining interest, it may retain such interest for its
own account or it may sell, transfer, farm-out or otherwise convey all or a portion of such remaining interest to non-affiliated industry members, which may occur either before or after the transfer of the interests in the same properties to the
Partnership. The General Partner or its affiliates may realize a profit on the interests or may be carried to some extent with respect to its cost obligations in connection with any drilling on such properties and any such profit or interests will
be strictly for the account of the General Partner or its affiliates and the Partnership will have no claim with respect thereto. The General Partner or its affiliates may not retain any overrides or other burdens on the property conveyed to the
Partnership (other than overriding royalty interests granted to geologists and other persons employed or retained by the General Partner or its affiliates) and may not enter into any farm-out arrangements with respect to its retained interest except
to non-affiliated third parties or other programs managed by the General Partner or its affiliates. 
 Partnership Assets

 The General Partner will not take any action with respect to assets or property of the Partnership which does not benefit primarily
the Partnership as a whole. The General Partner will not utilize the funds of the Partnership as compensating balances for the benefit of the General Partner or its affiliates. All benefits from marketing arrangements or other relationships
affecting property of the Partnership will be fairly and equitably apportioned according to the respective interests of the Partnership and the General Partner. 

  
 35 









 The Partnership Agreement provides that when the Partnership is terminated, there will be an accounting with
respect to its assets, liabilities and accounts. The Partnership’s physical property and its oil and gas properties may be sold for cash. Except in the case of an election by the General Partner to terminate the Partnership before the tenth
anniversary of the Effective Date, Partnership Properties may be sold to the General Partner or any of its affiliates for their fair market value as determined in good faith by the General Partner. 

Transactions with the General Partner or Affiliates 
 UNIT provides through its subsidiary Unit Drilling Company contract drilling services in the ordinary course of its business. UNIT also owns Superior Pipeline Company, L.L.C. which is engaged in the
business of buying and building gas gathering systems. It is anticipated that the Partnership will obtain services, equipment and supplies from one or all of such persons. In addition, UNIT may supply other goods or services to the Partnership. The
terms of any contracts or agreements between the Partnership and UNIT or any affiliate will be no less favorable to the Partnership than those of comparable contracts or agreements entered into, and will be at prices not in excess of (or in the case
of purchases of production, less than) those charged in the same geographical area, by non-affiliated persons or companies dealing at arm’s length. 
 For its services as a drilling contractor, Unit Drilling Company will charge the Partnership on either a daywork (a specified per day rate for each day a drilling rig is on the drill site), a footage (a
specified rate per foot drilled) or a turnkey (specified amount for drilling the well) basis. The rate charged by Unit Drilling Company for such services will be the same as those offered to unaffiliated third parties in the same or similar
geographic areas. 
 Right of Presentment Price Determination 
 Under the terms of the Partnership Agreement, a Limited Partner can, subject to certain conditions, require the General Partner to purchase his or her Units at a price determined by the application of a
stated formula to the estimated future net revenues attributable to the Partnership’s estimated proved reserves. See “TERMS OF THE OFFERING — Right of Presentment.” It is anticipated that if an independent engineering firm makes
an evaluation of the proved reserves of the Partnership, the result of that evaluation will be used in determining the price to be paid to a Limited Partner exercising his or her right of presentment. However, if no such independent evaluation is
made, the right of presentment purchase price will be determined by using the proved reserves and future net revenue estimates of the technical staff of the General Partner. 
 Receipt of Compensation Regardless of Profitability 
 The General Partner is entitled
to receive its fees and other compensation and reimbursements from the Partnership regardless of whether the Partnership operates at a profit or loss. See “PARTICIPATION IN COSTS AND REVENUES” and “COMPENSATION.” Such fees,
compensation and reimbursements will decrease the Limited Partners’ share of any profits generated by operations of the Partnership or increase losses if such operations should prove unprofitable. 

Legal Counsel 
 Conner &
Winters, LLP serves as special legal counsel for the General Partner. Such firm has performed legal services for the General Partner and UNIT and is expected to render legal services to the Partnership. Although such firm has indicated its intention
to withdraw from representation of the Partnership if conflicts of interest do in fact arise, there can be no assurance that representation of both the General Partner or UNIT and the Partnership by such firm will not be disadvantageous to the
Partnership. 
 FIDUCIARY RESPONSIBILITY 
 General 
 Under Oklahoma law, the General Partner will have a fiduciary duty to the
Limited Partners and consequently must exercise good faith, fairness and loyalty in the handling of the Partnership’s affairs. The General Partner must provide Limited Partners (or their representatives) with timely and full information
concerning matters 

  
 36 









 
affecting the business of the Partnership. Each Limited Partner may inspect the Partnership’s books and records on reasonable prior notice. The nature of the fiduciary duties of general
partners is an evolving area of law and prospective investors who have questions concerning the duties of the General Partner should consult with their counsel. 
 Regardless of the fiduciary obligations of the General Partner, the General Partner, UNIT or its affiliates, subject to any restrictions or requirements set forth in the Agreement, may: 

 

	 	•	 	 engage independently of the Partnership in all aspects of the oil and gas business, either for their own accounts or for the accounts of others;



  

	 	•	 	 sell interests in oil and gas properties held by them to, purchase oil and gas production from, and engage in other transactions with, the Partnership;



  

	 	•	 	 serve as general partner of other oil and gas drilling or income partnerships, including those which may be in competition with the Partnership; and



  

	 	•	 	 engage in other activities that may involve conflicts of interest. 


 See “CONFLICTS OF INTEREST.” Thus, unlike the strict duty of a fiduciary who must act solely in the best interests of his or her beneficiary, the Agreement permits the General Partner to
consider, among other things, the interests of other partnerships sponsored by the General Partner, UNIT or its affiliates in resolving investment and other conflicts of interest. The foregoing provisions permit the General Partner to conduct its
own operations and to act as the general partner of more than one similar partnership or investment program and for the Partnership to benefit from its experience resulting therefrom, but relieves the General Partner of the strict fiduciary duty of
a general partner acting as such for only one investment program at a time. These provisions are primarily intended to reconcile the applicable duties under Oklahoma law with the fact that the General Partner will manage and administer its own oil
and gas operations and a number of other oil and gas investment programs with which possible conflicts of interests may arise and resolve such conflicts in a manner consistent with the expectation of the investors in all such programs, the General
Partner’s fiduciary duties and customary business practices and statutes applicable thereto. 
 Liability and Indemnification

 The Agreement provides that the General Partner will perform its duties in an efficient and businesslike manner with due caution and
in accordance with established practices of the oil and gas industry. The Agreement further provides that the General Partner and its affiliates will not be liable to the Partnership or the Partners, and will be indemnified by the Partnership, for
any expense (including attorney fees), loss or damage incurred by reason of any act or omission performed or omitted in good faith in a manner reasonably believed by the General Partner or its affiliates to be within the scope of authority and in
the best interest of the Partnership or the Partners unless the General Partner or its affiliates is guilty of gross negligence or willful misconduct. While not totally certain under Oklahoma law, absent specific provisions in the partnership
agreement to the contrary, a general partner of a limited partnership may be liable to its limited partners if it fails to conduct the partnership affairs with the same amount of care which ordinarily prudent persons would use in similar
circumstances. Consequently, the Agreement may be viewed as requiring a lesser standard of duty and care than what Oklahoma law might otherwise require of the General Partner. 
 Any claim against the Partnership for indemnification must be satisfied only out of Partnership assets including insurance proceeds, if any, and none of the Limited Partners will have personal liability
therefore. 
 The Limited Partners may have more limited rights of action than they would have absent the liability and indemnification
provisions above. Moreover, indemnification enforced by the General Partner under such provisions will reduce the assets of the Partnership. It should be noted, however, that it is the position of the Securities and Exchange Commission
(“Commission”) that any attempt to limit the liability of a general partner or to indemnify a general partner under the federal securities laws is contrary to public policy and, therefore, unenforceable. The General Partner has been
advised of the position of the Commission. 

  
 37 









 Generally, the Limited Partners’ remedy for the General Partner’s breach of a fiduciary duty will
be to bring a legal action against the General Partner to recover any damages, generally measured by the benefits earned by the General Partner as a result of the fiduciary breach. Additionally, Limited Partners may also be able to obtain other
forms of relief, including injunctive relief. The Act provides that a limited partner may bring an action in the name of a limited partnership (a partnership derivative action) to recover a judgment in its favor if general partners with authority to
do so have refused to bring the action or if an effort to cause such general partners to bring the action is not likely to succeed. 
 PRIOR ACTIVITIES 
 UNIT has been engaged in oil and gas exploration and development
operations since late 1974 and has conducted oil and gas drilling programs using the limited partnership format since 1979. The following table depicts the drilling results achieved as of September 30, 2010 by UNIT during each year since 1975.
Because of the unpredictability of oil and gas exploration in general, such results should not be considered indicative of the results that may be achieved by the Partnership. 

 

																																	
	Year Ended	    	Gross Wells(2)	 	    	Net Wells(3)	 
	 December 31(1)
	    	Total	 	    	Oil	 	    	Gas	 	    	Dry	 	    	Total	 	    	Oil	 	    	Gas	 	    	Dry	 
	 1975 Exploratory
	    	 	2	  	    	 	0	  	    	 	2	  	    	 	0	  	    	 	.01	  	    	 	0	  	    	 	.01	  	    	 	0	  
	 Development
	    	 	4	  	    	 	0	  	    	 	2	  	    	 	2	  	    	 	.07	  	    	 	0	  	    	 	.03	  	    	 	.04	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 	6	  	    	 	0	  	    	 	4	  	    	 	2	  	    	 	.08	  	    	 	0	  	    	 	.04	  	    	 	.04	  
									
	 1976 Exploratory
	    	 	1	  	    	 	0	  	    	 	0	  	    	 	1	  	    	 	.01	  	    	 	0	  	    	 	0	  	    	 	.01	  
	 Development
	    	 	8	  	    	 	0	  	    	 	6	  	    	 	2	  	    	 	.29	  	    	 	0	  	    	 	.28	  	    	 	.01	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 	9	  	    	 	0	  	    	 	6	  	    	 	3	  	    	 	.30	  	    	 	0	  	    	 	.28	  	    	 	.02	  
									
	 1977 Exploratory
	    	 	9	  	    	 	0	  	    	 	3	  	    	 	6	  	    	 	1.50	  	    	 	0	  	    	 	.45	  	    	 	1.05	  
	 Development
	    	 	16	  	    	 	0	  	    	 	9	  	    	 	7	  	    	 	2.00	  	    	 	0	  	    	 	.70	  	    	 	1.30	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 	25	  	    	 	0	  	    	 	12	  	    	 	13	  	    	 	3.50	  	    	 	0	  	    	 	1.15	  	    	 	2.35	  
									
	 1978 Exploratory
	    	 	8	  	    	 	1	  	    	 	1	  	    	 	6	  	    	 	1.17	  	    	 	.34	  	    	 	.15	  	    	 	.68	  
	 Development
	    	 	26	  	    	 	0	  	    	 	13	  	    	 	13	  	    	 	2.64	  	    	 	0	  	    	 	.76	  	    	 	1.88	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 	34	  	    	 	1	  	    	 	14	  	    	 	19	  	    	 	3.81	  	    	 	.34	  	    	 	.91	  	    	 	2.56	  
									
	 1979 Exploratory
	    	 	10	  	    	 	0	  	    	 	5	  	    	 	5	  	    	 	1.40	  	    	 	0	  	    	 	.76	  	    	 	.64	  
	 Development
	    	 	16	  	    	 	1	  	    	 	8	  	    	 	7	  	    	 	1.99	  	    	 	.06	  	    	 	.95	  	    	 	.98	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
									
		    	 	26	  	    	 	1	  	    	 	13	  	    	 	12	  	    	 	3.39	  	    	 	.06	  	    	 	1.71	  	    	 	1.62	  
									
	 1980 Exploratory
	    	 	1	  	    	 	0	  	    	 	1	  	    	 	0	  	    	 	1.28	  	    	 	0	  	    	 	.23	  	    	 	1.05	  
	 Development
	    	 	10	  	    	 	0	  	    	 	8	  	    	 	2	  	    	 	3.13	  	    	 	0	  	    	 	.85	  	    	 	2.28	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 	11	  	    	 	0	  	    	 	9	  	    	 	2	  	    	 	4.41	  	    	 	0	  	    	 	1.08	  	    	 	3.33	  
									
	 1981 Exploratory
	    	 	14	  	    	 	1	  	    	 	4	  	    	 	9	  	    	 	1.12	  	    	 	.02	  	    	 	.16	  	    	 	.94	  
	 Development
	    	 	66	  	    	 	18	  	    	 	29	  	    	 	19	  	    	 	7.38	  	    	 	2.96	  	    	 	1.77	  	    	 	2.65	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	80	  	    	 	19	  	    	 	33	  	    	 	28	  	    	 	8.50	  	    	 	2.98	  	    	 	1.93	  	    	 	3.59	  
									
	 1982 Exploratory
	    	 	40	  	    	 	5	  	    	 	9	  	    	 	26	  	    	 	3.39	  	    	 	.60	  	    	 	.32	  	    	 	2.47	  
	 Development
	    	 	100	  	    	 	22	  	    	 	51	  	    	 	27	  	    	 	11.70	  	    	 	4.70	  	    	 	2.71	  	    	 	4.29	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	140	  	    	 	27	  	    	 	60	  	    	 	53	  	    	 	15.09	  	    	 	5.30	  	    	 	3.03	  	    	 	6.76	  
									
	 1983 Exploratory
	    	 	6	  	    	 	2	  	    	 	0	  	    	 	4	  	    	 	1.31	  	    	 	.72	  	    	 	0	  	    	 	.59	  
	 Development
	    	 	72	  	    	 	18	  	    	 	26	  	    	 	28	  	    	 	8.01	  	    	 	3.45	  	    	 	1.17	  	    	 	3.39	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	78	  	    	 	20	  	    	 	26	  	    	 	32	  	    	 	9.32	  	    	 	4.17	  	    	 	1.17	  	    	 	3.98	  
									
	 1984 Exploratory
	    	 	2	  	    	 	1	  	    	 	1	  	    	 	0	  	    	 	.52	  	    	 	.49	  	    	 	.03	  	    	 	0	  
	 Development
	    	 	50	  	    	 	15	  	    	 	22	  	    	 	13	  	    	 	6.81	  	    	 	3.42	  	    	 	2.74	  	    	 	.65	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	52	  	    	 	16	  	    	 	23	  	    	 	13	  	    	 	7.33	  	    	 	3.91	  	    	 	2.77	  	    	 	.65	  
									
	 1985 Exploratory
	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  
	 Development
	    	 	38	  	    	 	11	  	    	 	16	  	    	 	11	  	    	 	8.32	  	    	 	2.89	  	    	 	2.39	  	    	 	3.04	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	38	  	    	 	11	  	    	 	16	  	    	 	11	  	    	 	8.32	  	    	 	2.89	  	    	 	2.39	  	    	 	3.04	  
									
	 1986 Exploratory
	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  
	 Development
	    	 	21	  	    	 	4	  	    	 	6	  	    	 	11	  	    	 	3.85	  	    	 	.81	  	    	 	1.01	  	    	 	2.03	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	21	  	    	 	4	  	    	 	6	  	    	 	11	  	    	 	3.85	  	    	 	.81	  	    	 	1.01	  	    	 	2.03	  


  
 38 










																																	
	 Year Ended

December
31(1)
	    	Gross Wells(2)	 	    	Net Wells(3)	 
	    	Total	 	    	Oil	 	    	Gas	 	    	Dry	 	    	Total	 	    	Oil	 	    	Gas	 	    	Dry	 
	 1987 Exploratory
	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  
	 Development
	    	 	46	  	    	 	23	  	    	 	10	  	    	 	13	  	    	 	11.91	  	    	 	7.95	  	    	 	1.76	  	    	 	2.34	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	46	  	    	 	23	  	    	 	10	  	    	 	13	  	    	 	11.91	  	    	 	7.95	  	    	 	1.76	  	    	 	2.34	  
									
	 1988 Exploratory
	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  
	 Development
	    	 	39	  	    	 	20	  	    	 	10	  	    	 	9	  	    	 	22.56	  	    	 	14.77	  	    	 	4.05	  	    	 	3.74	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	39	  	    	 	20	  	    	 	10	  	    	 	9	  	    	 	22.56	  	    	 	14.77	  	    	 	4.05	  	    	 	3.74	  
									
	 1989 Exploratory
	    	 	3	  	    	 	0	  	    	 	1	  	    	 	2	  	    	 	1.97	  	    	 	0	  	    	 	.47	  	    	 	1.50	  
	 Development
	    	 	40	  	    	 	12	  	    	 	15	  	    	 	13	  	    	 	18.83	  	    	 	8.81	  	    	 	4.13	  	    	 	5.89	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	43	  	    	 	12	  	    	 	16	  	    	 	15	  	    	 	20.80	  	    	 	8.81	  	    	 	4.60	  	    	 	7.39	  
									
	 1990 Exploratory
	    	 	5	  	    	 	0	  	    	 	2	  	    	 	3	  	    	 	1.22	  	    	 	0	  	    	 	.12	  	    	 	1.10	  
	 Development
	    	 	35	  	    	 	11	  	    	 	14	  	    	 	10	  	    	 	16.53	  	    	 	8.38	  	    	 	3.52	  	    	 	4.63	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	40	  	    	 	11	  	    	 	16	  	    	 	13	  	    	 	17.75	  	    	 	8.38	  	    	 	3.64	  	    	 	5.73	  
									
	 1991 Exploratory
	    	 	4	  	    	 	0	  	    	 	0	  	    	 	4	  	    	 	.82	  	    	 	0	  	    	 	0	  	    	 	.82	  
	 Development
	    	 	28	  	    	 	10	  	    	 	9	  	    	 	9	  	    	 	15.88	  	    	 	8.61	  	    	 	3.91	  	    	 	3.36	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	32	  	    	 	10	  	    	 	9	  	    	 	13	  	    	 	16.70	  	    	 	8.61	  	    	 	3.91	  	    	 	4.18	  
									
	 1992 Exploratory
	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  
	 Development
	    	 	18	  	    	 	1	  	    	 	11	  	    	 	6	  	    	 	5.81	  	    	 	1.00	  	    	 	3.33	  	    	 	1.48	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	18	  	    	 	1	  	    	 	11	  	    	 	6	  	    	 	5.81	  	    	 	1.00	  	    	 	3.33	  	    	 	1.48	  
									
	 1993 Exploratory
	    	 	1	  	    	 	0	  	    	 	0	  	    	 	1	  	    	 	.10	  	    	 	0	  	    	 	0	  	    	 	.10	  
	 Development
	    	 	16	  	    	 	9	  	    	 	6	  	    	 	1	  	    	 	12.48	  	    	 	8.98	  	    	 	3.32	  	    	 	.18	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	17	  	    	 	9	  	    	 	6	  	    	 	2	  	    	 	12.58	  	    	 	8.98	  	    	 	3.32	  	    	 	.28	  
									
	 1994 Exploratory
	    	 	3	  	    	 	0	  	    	 	1	  	    	 	2	  	    	 	1.71	  	    	 	0	  	    	 	.95	  	    	 	.76	  
	 Development
	    	 	57	  	    	 	5	  	    	 	40	  	    	 	12	  	    	 	25.79	  	    	 	4.75	  	    	 	14.14	  	    	 	6.90	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	60	  	    	 	5	  	    	 	41	  	    	 	14	  	    	 	27.50	  	    	 	4.75	  	    	 	15.09	  	    	 	7.66	  
									
	 1995 Exploratory
	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  
	 Development
	    	 	45	  	    	 	15	  	    	 	24	  	    	 	6	  	    	 	14.94	  	    	 	4.67	  	    	 	8.04	  	    	 	2.23	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	45	  	    	 	15	  	    	 	24	  	    	 	6	  	    	 	14.94	  	    	 	4.67	  	    	 	8.04	  	    	 	2.23	  
									
	 1996 Exploratory
	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  
	 Development
	    	 	70	  	    	 	10	  	    	 	51	  	    	 	9	  	    	 	32.09	  	    	 	7.61	  	    	 	20.09	  	    	 	4.39	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	70	  	    	 	10	  	    	 	51	  	    	 	9	  	    	 	32.09	  	    	 	7.61	  	    	 	20.09	  	    	 	4.39	  
									
	 1997 Exploratory
	    	 	2	  	    	 	0	  	    	 	0	  	    	 	2	  	    	 	2.00	  	    	 	0	  	    	 	0	  	    	 	2.00	  
	 Development
	    	 	80	  	    	 	8	  	    	 	58	  	    	 	14	  	    	 	35.94	  	    	 	4.35	  	    	 	23.29	  	    	 	8.30	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	82	  	    	 	8	  	    	 	58	  	    	 	16	  	    	 	37.94	  	    	 	4.35	  	    	 	23.29	  	    	 	10.30	  
									
	 1998 Exploratory
	    	 	2	  	    	 	0	  	    	 	1	  	    	 	1	  	    	 	.63	  	    	 	0	  	    	 	.375	  	    	 	.26	  
	 Development
	    	 	76	  	    	 	3	  	    	 	52	  	    	 	21	  	    	 	30.17	  	    	 	.31	  	    	 	18.750	  	    	 	11.11	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	78	  	    	 	3	  	    	 	53	  	    	 	22	  	    	 	30.80	  	    	 	.31	  	    	 	19.125	  	    	 	11.37	  
									
	 1999 Exploratory
	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  
	 Development
	    	 	51	  	    	 	1	  	    	 	42	  	    	 	8	  	    	 	21.8	  	    	 	.4	  	    	 	17.4	  	    	 	4.0	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	51	  	    	 	1	  	    	 	42	  	    	 	8	  	    	 	21.8	  	    	 	.4	  	    	 	17.4	  	    	 	4.0	  
									
	 2000 Exploratory
	    	 	2	  	    	 	0	  	    	 	2	  	    	 	0	  	    	 	1.72	  	    	 	0	  	    	 	1.72	  	    	 	0	  
	 Development
	    	 	98	  	    	 	7	  	    	 	73	  	    	 	18	  	    	 	38.37	  	    	 	1.45	  	    	 	28.55	  	    	 	8.37	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	100	  	    	 	7	  	    	 	75	  	    	 	18	  	    	 	40.09	  	    	 	1.45	  	    	 	30.27	  	    	 	8.37	  
									
	 2001 Exploratory
	    	 	3	  	    	 	0	  	    	 	0	  	    	 	3	  	    	 	2.03	  	    	 	0	  	    	 	0	  	    	 	2.03	  
	 Development
	    	 	123	  	    	 	7	  	    	 	94	  	    	 	22	  	    	 	49.94	  	    	 	1.08	  	    	 	34.12	  	    	 	14.74	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	126	  	    	 	7	  	    	 	94	  	    	 	25	  	    	 	51.97	  	    	 	1.08	  	    	 	34.12	  	    	 	16.77	  
									
	 2002 Exploratory
	    	 	6	  	    	 	0	  	    	 	2	  	    	 	4	  	    	 	1.34	  	    	 	0	  	    	 	.90	  	    	 	.44	  
	 Development
	    	 	91	  	    	 	4	  	    	 	63	  	    	 	24	  	    	 	47.15	  	    	 	1.92	  	    	 	29.71	  	    	 	15.52	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	97	  	    	 	4	  	    	 	65	  	    	 	28	  	    	 	48.49	  	    	 	1.92	  	    	 	30.61	  	    	 	15.96	  


  
 39 










																																	
	 Year Ended

December
31(1)
	    	Gross Wells(2)	 	    	Net Wells(3)	 
	    	Total	 	    	Oil	 	    	Gas	 	    	Dry	 	    	Total	 	    	Oil	 	    	Gas	 	    	Dry	 
	 2003 Exploratory
	    	 	4	  	    	 	1	  	    	 	3	  	    	 	0	  	    	 	2.40	  	    	 	.20	  	    	 	2.20	  	    	 	0	  
	 Development
	    	 	145	  	    	 	5	  	    	 	119	  	    	 	21	  	    	 	59.17	  	    	 	2.13	  	    	 	44.31	  	    	 	12.73	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	149	  	    	 	6	  	    	 	122	  	    	 	21	  	    	 	61.57	  	    	 	2.33	  	    	 	46.51	  	    	 	12.73	  
									
	 2004 Exploratory
	    	 	14	  	    	 	1	  	    	 	7	  	    	 	6	  	    	 	6.29	  	    	 	.98	  	    	 	2.75	  	    	 	2.56	  
	 Development
	    	 	156	  	    	 	18	  	    	 	114	  	    	 	24	  	    	 	65.11	  	    	 	7.33	  	    	 	45.28	  	    	 	12.50	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	170	  	    	 	19	  	    	 	121	  	    	 	30	  	    	 	71.40	  	    	 	8.31	  	    	 	48.03	  	    	 	15.06	  
									
	 2005 Exploratory
	    	 	8	  	    	 	1	  	    	 	5	  	    	 	2	  	    	 	3.91	  	    	 	.32	  	    	 	1.59	  	    	 	2.00	  
	 Development
	    	 	184	  	    	 	17	  	    	 	154	  	    	 	13	  	    	 	68.37	  	    	 	5.68	  	    	 	56.93	  	    	 	5.76	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	192	  	    	 	18	  	    	 	159	  	    	 	15	  	    	 	72.28	  	    	 	6.00	  	    	 	58.52	  	    	 	7.76	  
									
	 2006 Exploratory
	    	 	10	  	    	 	0	  	    	 	4	  	    	 	6	  	    	 	4.94	  	    	 	0	  	    	 	2.21	  	    	 	2.73	  
	 Development
	    	 	234	  	    	 	12	  	    	 	198	  	    	 	24	  	    	 	81.02	  	    	 	2.71	  	    	 	68.19	  	    	 	10.12	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	244	  	    	 	12	  	    	 	202	  	    	 	30	  	    	 	85.96	  	    	 	2.71	  	    	 	70.40	  	    	 	12.85	  
									
	 2007 Exploratory
	    	 	15	  	    	 	2	  	    	 	7	  	    	 	6	  	    	 	7.84	  	    	 	0.51	  	    	 	4.61	  	    	 	2.72	  
	 Development
	    	 	238	  	    	 	17	  	    	 	194	  	    	 	27	  	    	 	86.39	  	    	 	5.57	  	    	 	67.43	  	    	 	13.39	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	253	  	    	 	19	  	    	 	201	  	    	 	33	  	    	 	94.23	  	    	 	6.08	  	    	 	72.04	  	    	 	16.11	  
									
	 2008 Exploratory
	    	 	15	  	    	 	3	  	    	 	5	  	    	 	7	  	    	 	8.23	  	    	 	1.45	  	    	 	4.18	  	    	 	2.60	  
	 Development
	    	 	263	  	    	 	55	  	    	 	182	  	    	 	26	  	    	 	126.08	  	    	 	26.62	  	    	 	85.49	  	    	 	13.97	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	278	  	    	 	58	  	    	 	187	  	    	 	33	  	    	 	134.31	  	    	 	28.07	  	    	 	89.67	  	    	 	16.57	  
									
	 2009 Exploratory
	    	 	8	  	    	 	2	  	    	 	3	  	    	 	3	  	    	 	4.88	  	    	 	0.28	  	    	 	2.50	  	    	 	2.10	  
	 Development
	    	 	87	  	    	 	20	  	    	 	64	  	    	 	3	  	    	 	37.22	  	    	 	5.37	  	    	 	30.29	  	    	 	1.56	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	95	  	    	 	22	  	    	 	67	  	    	 	6	  	    	 	42.10	  	    	 	5.65	  	    	 	32.79	  	    	 	3.66	  
	
	 Period of January 1, 2010 to September 30, 2010
	   

									
	 2010 Exploratory
	    	 	12	  	    	 	3	  	    	 	5	  	    	 	4	  	    	 	8.58	  	    	 	1.41	  	    	 	4.05	  	    	 	3.12	  
	 Development
	    	 	93	  	    	 	43	  	    	 	43	  	    	 	7	  	    	 	48.75	  	    	 	20.13	  	    	 	24.36	  	    	 	4.26	  
		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
	 Total
	    	 	105	  	    	 	46	  	    	 	48	  	    	 	11	  	    	 	57.33	  	    	 	21.54	  	    	 	28.41	  	    	 	7.38	  

  

	(1)	Except as indicated, the figures used in this table relate to wells drilled and completed during each of the 12 month periods ended July 31 or December 31, as
the case may be. Oil wells and gas wells shown include both producing wells and wells capable of production. 


	(2)	“Gross Wells” refers to the total number of wells in which there was participation by UNIT. 


	(3)	“Net Wells” refers to the aggregate leasehold working interest of UNIT in such wells. For example, a 50% leasehold working interest in a well drilled
represents 1.0 Gross Well, but a .50 Net Well. 

 Prior Employee Programs 

During the period of 1979 to 1983, persons who were designated key employees of UNIT by its board of directors participated in the Unit Key Employee
Exploration Funds (the “Funds”). These Funds were formed as general partnerships for the purpose of participating in 10% of all of the exploration and development operations conducted by UNIT during a specified period. Except for the Fund
formed in 1983, each of the prior Funds served as one of the general partners in at least one of the prior drilling programs sponsored by UNIT and was allocated 10% of the expenses and revenues allocable to the general partners as a group. In each
of these Funds the costs charged to it in connection with its operations were financed with the proceeds of bank borrowings and out of the Funds’ share of revenues. 
 The 1983 Fund served as the sole capital limited partner in the Unit 1983-A Oil and Gas Program and as such made no contribution to the capital of that program and shared in 10% of the costs and revenues
otherwise allocable to the General Partner after the distributions to the General Partner from the program equaled the amount of its contributions thereto plus UNIT’s interest costs with respect to the unrecovered amount of its contributions.


  
 40 









 Because of the differences in structure, format and plan of operations between the prior Funds and the
Partnership and because of the uncertainties which are inherent in oil and gas operations generally, the results achieved by the prior Funds should not be considered indicative of the results the Partnership may achieve. 

For each year from 1984 through 2010, a separate Employee Program was formed as an Oklahoma limited partnership with UNIT or UPC as its sole general
partner (UPC now serves as the sole general partner of each of these Employee Programs) and with eligible employees and directors of UNIT and its subsidiaries who subscribed for units therein as the limited partners. Each Employee Program
participated on a proportionate basis (to the extent of 10% of the General Partner’s interest in each case except for the 1986 and 1987 Employee Programs, in which case the percentage participation was 15% and the 1992 - 2001 Employee Programs,
in which case the percentage was 5% and the 2002 and 2003 Employee Programs in which case the percentage was 2 1/2% and 2007, 2008, 2009 and 2010 Employee Program in which case the percentage was 1%) in all of UNIT’s oil and gas exploration and
development operations conducted during the calendar year for which the program was formed beginning with its date of formation if it was formed after January 1. Although the terms and provisions of these Employee Programs are virtually
identical to those of the Partnership, because of the unpredictability of oil and gas exploration and development in general, the results for the Employee Programs shown below should not be considered indicative of the results that may be achieved
by the Partnership. 
 As noted above, the Funds and the Employee Programs have participated in a specified percentage (ranging from 1% to 15%,
depending on the program) of virtually all of UNIT’s or the General Partner’s exploration and development operations conducted since the latter half of 1979. Thus, the drilling results of these partnerships would be proportionate to those
drilling results of UNIT for the periods beginning after the fiscal year ended July 31, 1979 shown above. 
 Results of the Prior Oil
and Gas Programs 
 In each of the General Partner’s prior oil and gas programs other than the Unit 1983-A Oil and Gas Program and
the Unit 1984 Oil and Gas Limited Partnership, one of the prior Funds also served as a general partner. The 1983 Fund served as the sole capital limited partner of the Unit 1983-A Oil and Gas Program and the 1984 Employee Program serves as a general
partner of the Unit 1984 Oil and Gas Limited Partnership. The Unit 1979 Oil and Gas Program was the first limited partnership drilling program of which UNIT was a sponsor. The revenue sharing terms of the 1979 Program was generally 70% to the
limited partners and 30% to the general partners until 150% program payout at which time the revenues were to be shared 55% to the limited partners and 45% to the general partners. The 1979 Program was dissolved effective July 1, 2003. The
revenue sharing terms of the Unit 1980 Oil and Gas Program were generally 60% to the limited partners and 40% to the general partners. The revenue sharing terms of the Unit 1981 Oil and Gas Program were generally 70% to the limited partners and 30%
to the general partners until program payout and 50% to the limited partners and 50% to the general partners thereafter. The revenue sharing terms of the Unit 1981-II Oil and Gas Program, the Unit 1982-A Oil and Gas Program and the Unit 1982-B Oil
and Gas Program (60% to the limited partners and 40% to the general partners) were substantially the same as those of the Unit 1983-A Oil and Gas Program and the Unit 1984 Oil and Gas Limited Partnership (65% to the limited partners and 35% to the
general partner) except that the general partners’ cost percentage and the general partners’ revenue share in each of those prior programs could not be less than 25%. The following tables depict the drilling results at September 30,
2010, and the economic results at September 30, 2010 of prior oil and gas programs and the 1984 - 2010 Employee Programs. On September 12, 1986, in connection with a major restructuring and recapitalization, UNIT acquired all of the assets
and liabilities of the programs formed during 1980 through 1983 and these programs have now been dissolved. Effective December 31, 1993, pursuant to an Agreement and Plan of Merger, dated as of December 28, 1993, all of the assets and all
of the liabilities of the 1984, 1985, 1986, 1987, 1988, 1989 and 1990 Employee Programs were merged with and consolidated into a new Employee Program called the Unit Consolidated Employee Oil and Gas Limited Partnership, an Oklahoma Limited
Partnership which was formed November 30, 1993 (the “Consolidated Program”). Effective December 31, 2002, pursuant to an Agreement and Plan of Merger, dated December 27, 2002, all of the assets and all of the liabilities of
the 1991, 1992, 1993, 1994, 1995, 1996, 1997, 1998, and 1999 Employee Programs were merged with and consolidated into to the Consolidated Program. The Consolidated 

  
 41 









 
Program holds no assets other than those acquired in the mergers with the 1984 through 1999 Employee Programs. All of the Employee Programs formed since 2000 continue in existence. Certain of
these programs have not completed all of their drilling and development operations. Moreover, because of the unpredictability of oil and gas exploration and development in general, the results shown below should not be considered indicative of the
results that may be achieved by the Partnership. 
 DRILLING RESULTS 

As of September 30, 2010 
  

																																			
	 	    	 	    	Gross Wells	 	    	Net Wells	 
	 Programs
	    	  	    	Total	 	    	Oil	 	    	Gas	 	    	Dry	 	    	Total	 	    	Oil	 	    	Gas	 	    	Dry	 
	 1979(1)
	    	Exploratory Wells	    	 	6	  	    	 	0	  	    	 	2	  	    	 	4	  	    	 	2.43	  	    	 	0.00	  	    	 	0.65	  	    	 	1.78	  
		    	Development Wells	    	 	21	  	    	 	16	  	    	 	1	  	    	 	4	  	    	 	17.28	  	    	 	14.14	  	    	 	0.03	  	    	 	3.11	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	Total	    	 	27	  	    	 	16	  	    	 	3	  	    	 	8	  	    	 	19.71	  	    	 	14.14	  	    	 	0.68	  	    	 	4.89	  
										
	 1980(2)
	    	Exploratory
Wells	    	 	15	  	    	 	2	  	    	 	5	  	    	 	8	  	    	 	5.65	  	    	 	0.50	  	    	 	2.14	  	    	 	3.01	  
		    	Development Wells	    	 	32	  	    	 	5	  	    	 	15	  	    	 	12	  	    	 	12.77	  	    	 	1.17	  	    	 	5.75	  	    	 	5.85	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	Total	    	 	47	  	    	 	7	  	    	 	20	  	    	 	20	  	    	 	18.42	  	    	 	1.67	  	    	 	7.89	  	    	 	8.86	  
										
	 1981(2)
	    	Exploratory Wells	    	 	11	  	    	 	1	  	    	 	4	  	    	 	6	  	    	 	4.61	  	    	 	0.33	  	    	 	0.88	  	    	 	3.40	  
		    	Development Wells	    	 	67	  	    	 	14	  	    	 	34	  	    	 	19	  	    	 	21.77	  	    	 	5.03	  	    	 	6.61	  	    	 	10.13	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	Total	    	 	78	  	    	 	15	  	    	 	38	  	    	 	25	  	    	 	26.38	  	    	 	5.36	  	    	 	7.49	  	    	 	13.53	  
										
	 1981-II(2)
	    	Exploratory Wells	    	 	13	  	    	 	1	  	    	 	5	  	    	 	7	  	    	 	5.21	  	    	 	0.25	  	    	 	1.12	  	    	 	3.84	  
		    	Development Wells	    	 	45	  	    	 	3	  	    	 	29	  	    	 	13	  	    	 	9.07	  	    	 	0.69	  	    	 	4.78	  	    	 	3.60	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	Total	    	 	58	  	    	 	4	  	    	 	34	  	    	 	20	  	    	 	14.28	  	    	 	0.94	  	    	 	5.90	  	    	 	7.44	  
										
	 1982-A(2)
	    	Exploratory Wells	    	 	11	  	    	 	3	  	    	 	1	  	    	 	7	  	    	 	3.55	  	    	 	0.78	  	    	 	0.00	  	    	 	2.77	  
		    	Development Wells	    	 	69	  	    	 	23	  	    	 	22	  	    	 	24	  	    	 	25.22	  	    	 	13.09	  	    	 	3.59	  	    	 	8.54	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	Total	    	 	80	  	    	 	26	  	    	 	23	  	    	 	31	  	    	 	28.77	  	    	 	13.87	  	    	 	3.59	  	    	 	11.31	  
										
	 1982-B(2)
	    	Exploratory Wells	    	 	4	  	    	 	1	  	    	 	1	  	    	 	2	  	    	 	2.28	  	    	 	0.80	  	    	 	0.08	  	    	 	1.40	  
		    	Development Wells	    	 	41	  	    	 	16	  	    	 	9	  	    	 	16	  	    	 	18.60	  	    	 	9.47	  	    	 	1.01	  	    	 	8.12	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	Total	    	 	45	  	    	 	17	  	    	 	10	  	    	 	18	  	    	 	20.88	  	    	 	10.27	  	    	 	1.09	  	    	 	9.52	  
										
	 1983-A(2)
	    	Exploratory Wells	    	 	1	  	    	 	1	  	    	 	0	  	    	 	0	  	    	 	1.00	  	    	 	1.00	  	    	 	0.00	  	    	 	0.00	  
		    	Development Wells	    	 	26	  	    	 	14	  	    	 	10	  	    	 	2	  	    	 	6.60	  	    	 	4.39	  	    	 	1.27	  	    	 	0.94	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	Total	    	 	27	  	    	 	15	  	    	 	10	  	    	 	2	  	    	 	7.60	  	    	 	5.39	  	    	 	1.27	  	    	 	0.94	  
										
	 1984
	    	Exploratory Wells	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0.00	  	    	 	0.00	  	    	 	0.00	  	    	 	0.00	  
		    	Development Wells	    	 	21	  	    	 	1	  	    	 	10	  	    	 	10	  	    	 	5.89	  	    	 	.38	  	    	 	3.08	  	    	 	2.43	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	Total	    	 	21	  	    	 	1	  	    	 	10	  	    	 	10	  	    	 	5.89	  	    	 	.38	  	    	 	3.08	  	    	 	2.43	  

  

	(1)	Effective July 1, 2003 this program was dissolved. 


	(2)	On September 12, 1986, UNIT acquired all of the assets and liabilities of this Program and the Program has been dissolved. 


  
 42 









  EMPLOYEE PROGRAMS 
 As of September 30, 2010 
  

																																			
	 	    	Gross Wells	 	    	Net Wells	 
	 Programs
	    	Total	 	    	Oil	 	    	Gas	 	    	Dry	 	    	Total	 	    	Oil	 	    	Gas	 	    	Dry	 
	
1984(1)
	    	
Exploratory Wells
	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0.00	  	    	 	0.00	  	    	 	0.00	  	    	 	0.00	  
	 Empl.
	    	 Development Wells
	    	 	25	  	    	 	4	  	    	 	12	  	    	 	9	  	    	 	.14	  	    	 	.02	  	    	 	.06	  	    	 	.06	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	25	  	    	 	4	  	    	 	12	  	    	 	9	  	    	 	.14	  	    	 	.02	  	    	 	.06	  	    	 	.06	  
										
	
1985(1)
	    	 Exploratory Wells
	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0.00	  	    	 	0.00	  	    	 	0.00	  	    	 	0.00	  
	 Empl.
	    	 Development Wells
	    	 	30	  	    	 	8	  	    	 	10	  	    	 	12	  	    	 	.38	  	    	 	.12	  	    	 	.08	  	    	 	.18	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	30	  	    	 	8	  	    	 	10	  	    	 	12	  	    	 	.38	  	    	 	.12	  	    	 	.08	  	    	 	.18	  
										
	
1986(1)
	    	 Exploratory Wells
	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0.00	  	    	 	0.00	  	    	 	0.00	  	    	 	0.00	  
	 Empl.
	    	 Development Wells
	    	 	18	  	    	 	6	  	    	 	8	  	    	 	4	  	    	 	.48	  	    	 	.12	  	    	 	.30	  	    	 	.06	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	18	  	    	 	6	  	    	 	8	  	    	 	4	  	    	 	.48	  	    	 	.12	  	    	 	.30	  	    	 	.06	  
										
	
1987(1)
	    	 Exploratory Wells
	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0.00	  	    	 	0.00	  	    	 	0.00	  	    	 	0.00	  
	 Empl.
	    	 Development Wells
	    	 	21	  	    	 	12	  	    	 	5	  	    	 	4	  	    	 	1.17	  	    	 	.74	  	    	 	.25	  	    	 	.18	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	21	  	    	 	12	  	    	 	5	  	    	 	4	  	    	 	1.17	  	    	 	.74	  	    	 	.25	  	    	 	.18	  
										
	
1988(1)
	    	 Exploratory Wells
	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  
	 Empl.
	    	 Development Wells
	    	 	29	  	    	 	15	  	    	 	9	  	    	 	5	  	    	 	1.55	  	    	 	1.03	  	    	 	.28	  	    	 	.24	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	29	  	    	 	15	  	    	 	9	  	    	 	5	  	    	 	1.55	  	    	 	1.03	  	    	 	.28	  	    	 	.24	  
										
	
1989(1)
	    	 Exploratory Wells
	    				    				    				    				    				    				    				    			
	 Empl.
	    	 Development Wells
	    	 	32	  	    	 	7	  	    	 	14	  	    	 	11	  	    	 	1.48	  	    	 	.59	  	    	 	.36	  	    	 	.53	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	32	  	    	 	7	  	    	 	14	  	    	 	11	  	    	 	1.48	  	    	 	.59	  	    	 	.36	  	    	 	.53	  
										
	
1990(1)
	    	 Exploratory Wells
	    	 	5	  	    	 	0	  	    	 	2	  	    	 	3	  	    	 	.122	  	    	 	0	  	    	 	.01	  	    	 	.11	  
	 Empl.
	    	 Development Wells
	    	 	34	  	    	 	11	  	    	 	14	  	    	 	9	  	    	 	1.65	  	    	 	.83	  	    	 	.35	  	    	 	.46	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	39	  	    	 	11	  	    	 	16	  	    	 	12	  	    	 	1.78	  	    	 	.83	  	    	 	.36	  	    	 	.57	  
										
	
1991(2)
	    	 Exploratory Wells
	    	 	4	  	    	 	0	  	    	 	0	  	    	 	4	  	    	 	.08	  	    	 	0	  	    	 	0	  	    	 	.08	  
	 Empl.
	    	 Development Wells
	    	 	28	  	    	 	10	  	    	 	9	  	    	 	9	  	    	 	1.59	  	    	 	.86	  	    	 	.39	  	    	 	.34	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	32	  	    	 	10	  	    	 	9	  	    	 	13	  	    	 	1.67	  	    	 	.86	  	    	 	.39	  	    	 	.42	  
										
	
1992(2)
	    	 Exploratory Wells
	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  
	 Empl.
	    	 Development Wells
	    	 	18	  	    	 	1	  	    	 	11	  	    	 	6	  	    	 	.29	  	    	 	.05	  	    	 	.17	  	    	 	.07	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	18	  	    	 	1	  	    	 	11	  	    	 	6	  	    	 	.29	  	    	 	.05	  	    	 	.17	  	    	 	.07	  
										
	
1993(2)
	    	 Exploratory Wells
	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  
	 Empl.
	    	 Development Wells
	    	 	16	  	    	 	9	  	    	 	6	  	    	 	1	  	    	 	.63	  	    	 	.45	  	    	 	.17	  	    	 	.01	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	16	  	    	 	9	  	    	 	6	  	    	 	1	  	    	 	.63	  	    	 	.45	  	    	 	.17	  	    	 	.01	  
										
	
1994(2)
	    	 Exploratory Wells
	    	 	3	  	    	 	0	  	    	 	1	  	    	 	2	  	    	 	.09	  	    	 	0	  	    	 	.05	  	    	 	.04	  
	 Empl.
	    	 Development Wells
	    	 	57	  	    	 	5	  	    	 	40	  	    	 	12	  	    	 	1.29	  	    	 	.24	  	    	 	.70	  	    	 	.35	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	60	  	    	 	5	  	    	 	41	  	    	 	14	  	    	 	1.38	  	    	 	.24	  	    	 	.75	  	    	 	.39	  
										
	
1995(2)
	    	 Exploratory Wells
	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  
	 Empl.
	    	 Development Wells
	    	 	45	  	    	 	15	  	    	 	24	  	    	 	6	  	    	 	.74	  	    	 	.23	  	    	 	.40	  	    	 	.11	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	45	  	    	 	15	  	    	 	24	  	    	 	6	  	    	 	.74	  	    	 	.23	  	    	 	.40	  	    	 	.11	  
										
	
1996(2)
	    	 Exploratory Wells
	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  
	 Empl.
	    	 Development Wells
	    	 	53	  	    	 	7	  	    	 	38	  	    	 	8	  	    	 	1.24	  	    	 	.27	  	    	 	.76	  	    	 	.21	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	53	  	    	 	7	  	    	 	38	  	    	 	8	  	    	 	1.24	  	    	 	.27	  	    	 	.76	  	    	 	.21	  


  
 43 










																																			
	 	    	Gross Wells	 	    	Net Wells	 
	 Programs
	    	Total	 	    	Oil	 	    	Gas	 	    	Dry	 	    	Total	 	    	Oil	 	    	Gas	 	    	Dry	 
	
1997(2)
	    	 Exploratory Wells
	    	 	2	  	    	 	0	  	    	 	0	  	    	 	2	  	    	 	.10	  	    	 	0	  	    	 	0	  	    	 	.10	  
	 Empl.
	    	 Development Wells
	    	 	80	  	    	 	8	  	    	 	58	  	    	 	14	  	    	 	1.80	  	    	 	.22	  	    	 	1.16	  	    	 	.42	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	82	  	    	 	8	  	    	 	58	  	    	 	16	  	    	 	1.90	  	    	 	.22	  	    	 	1.16	  	    	 	.52	  
										
	
1998(2)
	    	 Exploratory Wells
	    	 	2	  	    	 	0	  	    	 	1	  	    	 	1	  	    	 	.03	  	    	 	0	  	    	 	.02	  	    	 	.01	  
	 Empl.
	    	 Development Wells
	    	 	76	  	    	 	3	  	    	 	52	  	    	 	21	  	    	 	1.51	  	    	 	.02	  	    	 	.94	  	    	 	.56	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	78	  	    	 	3	  	    	 	53	  	    	 	22	  	    	 	1.54	  	    	 	.02	  	    	 	.96	  	    	 	.57	  
										
	
1999(2)
	    	 Exploratory Wells
	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  	    	 	0	  
	 Empl.
	    	 Development Wells
	    	 	51	  	    	 	1	  	    	 	42	  	    	 	8	  	    	 	1.09	  	    	 	.02	  	    	 	.87	  	    	 	.20	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	51	  	    	 	1	  	    	 	42	  	    	 	8	  	    	 	1.09	  	    	 	.02	  	    	 	.87	  	    	 	.20	  
										
	 2000
	    	 Exploratory Wells
	    	 	2	  	    	 	0	  	    	 	2	  	    	 	0	  	    	 	.09	  	    	 	0	  	    	 	.09	  	    	 	0	  
	 Empl.
	    	 Development Wells
	    	 	98	  	    	 	7	  	    	 	73	  	    	 	18	  	    	 	1.92	  	    	 	.07	  	    	 	1.43	  	    	 	.42	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	100	  	    	 	7	  	    	 	75	  	    	 	18	  	    	 	2.01	  	    	 	.07	  	    	 	1.52	  	    	 	.42	  
										
	 2001
	    	 Exploratory Wells
	    	 	3	  	    	 	0	  	    	 	0	  	    	 	3	  	    	 	.05	  	    	 	0	  	    	 	0	  	    	 	.05	  
	 Empl.
	    	 Development Wells
	    	 	123	  	    	 	7	  	    	 	94	  	    	 	22	  	    	 	1.25	  	    	 	.03	  	    	 	.85	  	    	 	.37	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	126	  	    	 	7	  	    	 	94	  	    	 	25	  	    	 	1.30	  	    	 	.03	  	    	 	.85	  	    	 	.42	  
										
	 2002
	    	 Exploratory Wells
	    	 	6	  	    	 	0	  	    	 	2	  	    	 	4	  	    	 	.03	  	    	 	0	  	    	 	.02	  	    	 	.01	  
	 Empl.
	    	 Development Wells
	    	 	91	  	    	 	4	  	    	 	63	  	    	 	24	  	    	 	1.18	  	    	 	.05	  	    	 	.74	  	    	 	.39	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	97	  	    	 	4	  	    	 	65	  	    	 	28	  	    	 	1.21	  	    	 	.05	  	    	 	.76	  	    	 	.40	  
										
	 2003
	    	 Exploratory Wells
	    	 	4	  	    	 	1	  	    	 	3	  	    	 	0	  	    	 	.03	  	    	 	.01	  	    	 	.02	  	    	 	0	  
	 Empl.
	    	 Development Wells
	    	 	145	  	    	 	5	  	    	 	119	  	    	 	21	  	    	 	.59	  	    	 	.02	  	    	 	.44	  	    	 	.13	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	149	  	    	 	6	  	    	 	122	  	    	 	21	  	    	 	.62	  	    	 	.03	  	    	 	.46	  	    	 	.13	  
										
	 2004
	    	 Exploratory Wells
	    	 	14	  	    	 	1	  	    	 	7	  	    	 	6	  	    	 	.06	  	    	 	.01	  	    	 	.03	  	    	 	.03	  
	 Empl.
	    	 Development Wells
	    	 	156	  	    	 	18	  	    	 	114	  	    	 	24	  	    	 	.65	  	    	 	.07	  	    	 	.45	  	    	 	.12	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	170	  	    	 	19	  	    	 	121	  	    	 	30	  	    	 	.71	  	    	 	.08	  	    	 	.48	  	    	 	.15	  
										
	 2005
	    	 Exploratory Wells
	    	 	8	  	    	 	1	  	    	 	5	  	    	 	2	  	    	 	.04	  	    	 	0	  	    	 	.02	  	    	 	.02	  
	 Empl.
	    	 Development Wells
	    	 	184	  	    	 	17	  	    	 	154	  	    	 	13	  	    	 	.68	  	    	 	.05	  	    	 	.57	  	    	 	.06	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	192	  	    	 	18	  	    	 	159	  	    	 	15	  	    	 	.72	  	    	 	.05	  	    	 	.59	  	    	 	.08	  
										
	 2006
	    	 Exploratory Wells
	    	 	10	  	    	 	0	  	    	 	4	  	    	 	6	  	    	 	.05	  	    	 	0	  	    	 	.02	  	    	 	.03	  
	 Empl.
	    	 Development Wells
	    	 	234	  	    	 	12	  	    	 	198	  	    	 	24	  	    	 	.81	  	    	 	.03	  	    	 	.68	  	    	 	.10	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	244	  	    	 	12	  	    	 	202	  	    	 	30	  	    	 	.86	  	    	 	.03	  	    	 	.70	  	    	 	.13	  
										
	 2007
	    	 Exploratory Wells
	    	 	15	  	    	 	2	  	    	 	7	  	    	 	6	  	    	 	.08	  	    	 	0	  	    	 	.05	  	    	 	.03	  
	 Empl.
	    	 Development Wells
	    	 	238	  	    	 	17	  	    	 	194	  	    	 	27	  	    	 	.86	  	    	 	.06	  	    	 	.67	  	    	 	.13	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	253	  	    	 	19	  	    	 	201	  	    	 	33	  	    	 	.94	  	    	 	.06	  	    	 	.72	  	    	 	.16	  
										
	 2008
	    	 Exploratory Wells
	    	 	15	  	    	 	3	  	    	 	5	  	    	 	7	  	    	 	.08	  	    	 	.01	  	    	 	.04	  	    	 	.03	  
	 Empl.
	    	 Development Wells
	    	 	263	  	    	 	55	  	    	 	182	  	    	 	26	  	    	 	1.26	  	    	 	.27	  	    	 	.85	  	    	 	.14	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	278	  	    	 	58	  	    	 	187	  	    	 	33	  	    	 	1.34	  	    	 	.28	  	    	 	.89	  	    	 	.17	  
										
	 2009
	    	 Exploratory Wells
	    	 	8	  	    	 	2	  	    	 	3	  	    	 	3	  	    	 	.05	  	    	 	.01	  	    	 	.03	  	    	 	.02	  
	 Empl.
	    	 Development Wells
	    	 	87	  	    	 	20	  	    	 	64	  	    	 	3	  	    	 	.37	  	    	 	.05	  	    	 	.30	  	    	 	.01	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	 Total
	    	 	95	  	    	 	22	  	    	 	67	  	    	 	6	  	    	 	.42	  	    	 	.06	  	    	 	.33	  	    	 	.03	  


  
 44 










																																			
	 	    	Gross Wells	 	    	Net Wells	 
	 Programs
	    	Total	 	    	Oil	 	    	Gas	 	    	Dry	 	    	Total	 	    	Oil	 	    	Gas	 	    	Dry	 
	 Period of January 1, 2010 To September 30, 2010
	    				    				    				    				    				    				    				    			
										
	 2010
	    	 Exploratory Wells
	    	 	12	  	    	 	3	  	    	 	5	  	    	 	4	  	    	 	.09	  	    	 	.01	  	    	 	.04	  	    	 	.04	  
	 Empl.
	    	 Development Wells
	    	 	93	  	    	 	43	  	    	 	43	  	    	 	7	  	    	 	.49	  	    	 	.20	  	    	 	.25	  	    	 	.04	  
		    		    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 	    	 	 	 
		    	Total	    	 	105	  	    	 	46	  	    	 	48	  	    	 	11	  	    	 	.58	  	    	 	.21	  	    	 	.29	  	    	 	.08	  

  

	(1)	Effective December 31, 1993 this Program was merged with and into the Consolidated Program. 


	(2)	Effective December 31, 2002 this Program was merged with and into the Consolidated Program. 


  
 45 









 GENERAL PARTNERS’ PAYOUT TABLE(1) 

As of September 30, 2010 
  

													
	 Program
	  	Total
Expenditures
Including
Operating
Costs(2)	 	  	Total
Revenues
Before
Deducting
Operating
Costs	 	  	Total
Revenues
Before Deducting
Operating
Costs
for 3 Months Ended
September 30, 2010	 
	
1979(***)

	  	$	8,781,728	  	  	$	10,846,983	  	  	 	—  	  
	 1980
	  	 	4,043,599	  	  	 	4,044,424	  	  	 	—  	  
	 1981
	  	 	8,325,594	  	  	 	6,338,173	  	  	 	—  	  
	 1981-II
	  	 	6,642,875	  	  	 	3,995,616	  	  	 	—  	  
	 1982-A
	  	 	9,190,842	  	  	 	6,782,893	  	  	 	—  	  
	 1982-B
	  	 	4,213,710	  	  	 	3,126,326	  	  	 	—  	  
	 1983-A
	  	 	2,277,514	  	  	 	1,312,531	  	  	 	—  	  
	 1984
	  	 	3,608,640	  	  	 	3,156,334	  	  	 	18,333	  
	 1984 Employee(*)
	  	 	1,542	  	  	 	1,745	  	  	 	—  	  
	 1985 Employee(*)
	  	 	2,820	  	  	 	1,808	  	  	 	—  	  
	 1986 Energy Income Fund(**)
	  	 	3,781,630	  	  	 	2,428,652	  	  	 	11,945	  
	 1986 Employee(*)
	  	 	4,403	  	  	 	6,813	  	  	 	—  	  
	 1987 Employee(*)
	  	 	624,354	  	  	 	815,358	  	  	 	—  	  
	 1988 Employee(*)
	  	 	1,196,564	  	  	 	1,588,132	  	  	 	—  	  
	 1989 Employee(*)
	  	 	1,424,525	  	  	 	1,171,961	  	  	 	—  	  
	 1990 Employee(*)
	  	 	653,563	  	  	 	525,572	  	  	 	—  	  
	 1991 Employee(****)
	  	 	2,352,323	  	  	 	3,046,177	  	  	 	—  	  
	 1992 Employee(****)
	  	 	241,577	  	  	 	400,556	  	  	 	—  	  
	 1993 Employee(****)
	  	 	496,051	  	  	 	717,460	  	  	 	—  	  
	 1994 Employee(****)
	  	 	1,435,412	  	  	 	1,841,119	  	  	 	—  	  
	 1995 Employee(****)
	  	 	476,082	  	  	 	599,485	  	  	 	—  	  
	 1996 Employee(****)
	  	 	901,692	  	  	 	869,473	  	  	 	—  	  
	 1997 Employee(****)
	  	 	1,296,424	  	  	 	1,165,747	  	  	 	—  	  
	 1998 Employee(****)
	  	 	1,180,292	  	  	 	1,083,527	  	  	 	—  	  
	 1999 Employee(****)
	  	 	953,718	  	  	 	1,314,469	  	  	 	—  	  
	 Consolidated Program
	  	 	47,507	  	  	 	86,361	  	  	 	1,497	  
	 2000 Employee
	  	 	2,722,843	  	  	 	4,088,725	  	  	 	50,492	  
	 2001 Employee
	  	 	1,233,968	  	  	 	1,309,712	  	  	 	10,354	  
	 2002 Employee
	  	 	1,414,664	  	  	 	1,986,694	  	  	 	20,888	  
	 2003 Employee
	  	 	2,515,295	  	  	 	4,352,715	  	  	 	39,743	  
	 2004 Employee
	  	 	801,214	  	  	 	969,607	  	  	 	9,145	  
	 2005 Employee
	  	 	2,780,868	  	  	 	2,749,756	  	  	 	59,257	  
	 2006 Employee
	  	 	2,312,009	  	  	 	1,760,606	  	  	 	34,287	  
	 2007 Employee
	  	 	2,179,707	  	  	 	2,074,676	  	  	 	72,971	  
	 2008 Employee
	  	 	3,463,486	  	  	 	1,389,466	  	  	 	112,504	  
	 2009 Employee
	  	 	1,123,872	  	  	 	290,197	  	  	 	57,961	  
	 2010 Employee
	  	 	2,374,245	  	  	 	101,414	  	  	 	90,215	  

  

	(*)	 Effective December 31, 1993, this program was merged with and into the Consolidated Program. 



	(**)	 Formed primarily for purposes of acquiring producing oil and gas properties. 



	(***)	 Effective July 1, 2003 this program was dissolved. 



	(****)	 Effective December 31, 2002 this Program was merged with and into the Consolidated Program. 



  
 46 









 LIMITED PARTNERS’ PAYOUT TABLE(1) 

As of September 30, 2010 
  

													
	 Program
	  	Total
Expenditures
Including
Operating
Costs(2)	 	  	Total
Revenues
Before
Deducting
Operating
Costs	 	  	Total Revenues
Before 
Deducting
Operating Costs
for 3 Months Ended
September 30, 2010	 
	
1979(***)

	  	$	14,729,990	  	  	$	18,839,040	  	  	 	—  	  
	 1980
	  	 	17,688,367	  	  	 	6,949,008	  	  	 	—  	  
	 1981
	  	 	37,073,946	  	  	 	15,768,826	  	  	 	—  	  
	 1981-II
	  	 	18,638,600	  	  	 	7,028,946	  	  	 	—  	  
	 1982-A
	  	 	24,866,078	  	  	 	12,708,949	  	  	 	—  	  
	 1982-B
	  	 	12,069,566	  	  	 	5,367,312	  	  	 	—  	  
	 1983-A
	  	 	3,770,856	  	  	 	1,922,177	  	  	 	—  	  
	 1984
	  	 	3,630,532	  	  	 	3,250,937	  	  	 	18,333	  
	 1984 Employee(*)
	  	 	120,942	  	  	 	171,540	  	  	 	—  	  
	 1985 Employee(*)
	  	 	277,901	  	  	 	178,984	  	  	 	—  	  
	 1986 Energy Income Fund(**)
	  	 	3,329,928	  	  	 	4,763,406	  	  	 	17,917	  
	 1986 Employee(*)
	  	 	435,858	  	  	 	676,972	  	  	 	—  	  
	 1987 Employee(*)
	  	 	341,846	  	  	 	469,830	  	  	 	—  	  
	 1988 Employee(*)
	  	 	333,898	  	  	 	446,044	  	  	 	—  	  
	 1989 Employee(*)
	  	 	179,593	  	  	 	175,331	  	  	 	—  	  
	 1990 Employee(*)
	  	 	300,852	  	  	 	188,848	  	  	 	—  	  
	 1991 Employee(****)
	  	 	620,136	  	  	 	811,871	  	  	 	—  	  
	 1992 Employee(****)
	  	 	622,697	  	  	 	1,033,805	  	  	 	—  	  
	 1993 Employee(****)
	  	 	451,551	  	  	 	664,349	  	  	 	—  	  
	 1994 Employee(****)
	  	 	582,274	  	  	 	754,012	  	  	 	—  	  
	 1995 Employee(****)
	  	 	762,211	  	  	 	941,188	  	  	 	—  	  
	 1996 Employee(****)
	  	 	549,125	  	  	 	534,519	  	  	 	—  	  
	 1997 Employee(****)
	  	 	605,116	  	  	 	524,732	  	  	 	—  	  
	 1998 Employee(****)
	  	 	613,890	  	  	 	551,342	  	  	 	—  	  
	 1999 Employee(****)
	  	 	289,622	  	  	 	392,633	  	  	 	—  	  
	 Consolidated Program
	  	 	4,571,329	  	  	 	8,522,175	  	  	 	122,800	  
	 2000 Employee
	  	 	374,374	  	  	 	557,546	  	  	 	6,886	  
	 2001 Employee
	  	 	553,814	  	  	 	588,613	  	  	 	4,652	  
	 2002 Employee
	  	 	727,842	  	  	 	1,023,453	  	  	 	10,764	  
	 2003 Employee
	  	 	514,020	  	  	 	891,238	  	  	 	8,140	  
	 2004 Employee
	  	 	655,126	  	  	 	793,318	  	  	 	7,482	  
	 2005 Employee
	  	 	651,432	  	  	 	645,047	  	  	 	12,024	  
	 2006 Employee
	  	 	1,020,237	  	  	 	791,015	  	  	 	15,404	  
	 2007 Employee
	  	 	1,223,137	  	  	 	1,167,009	  	  	 	41,049	  
	 2008 Employee
	  	 	975,687	  	  	 	391,973	  	  	 	31,734	  
	 2009 Employee
	  	 	458,797	  	  	 	118,531	  	  	 	23,674	  
	 2010 Employee
	  	 	791,302	  	  	 	33,805	  	  	 	30,072	  

  

	(*)	 Effective December 31, 1993, this program was merged with and into the Consolidated Program. 



	(**)	 Formed primarily for purposes of acquiring producing oil and gas properties. 



	(***)	 Effective July 1, 2003, this program was dissolved. 



	(****)	 Effective December 31, 2002 this Program was merged with and into the Consolidated Program. 



  
 47 









 GENERAL PARTNERS’ NET CASH TABLE (1) 

As of September 30, 2010 
  

																					
	 Program
	  	Total
Capital
Expenditures(2)	 	  	Total
Revenues
Less
Operating
Costs	 	 	Total
Revenues
Less
Operating
Costs for
3 Months
Ended
Sept. 30,
2010	 	 	Total
Revenues
Distributed	 	  	Total
Revenues
Distributed
during the
3 Months
Ended
Sept. 30,
2010	 
	
1979(***)

	  	$	2,805,917	  	  	$	4,871,172	  	 	$	—  	  	 	$	3,961,014	  	  	$	—  	  
	 1980
	  	 	2,628,978	  	  	 	2,629,803	  	 	 	—  	  	 	 	2,635,751	  	  	 	—  	  
	 1981
	  	 	6,546,160	  	  	 	4,558,739	  	 	 	—  	  	 	 	5,368,272	  	  	 	—  	  
	 1981-II
	  	 	4,817,145	  	  	 	2,169,886	  	 	 	—  	  	 	 	2,609,000	  	  	 	—  	  
	 1982-A
	  	 	6,297,972	  	  	 	3,890,023	  	 	 	—  	  	 	 	3,755,000	  	  	 	—  	  
	 1982-B
	  	 	2,565,504	  	  	 	1,478,120	  	 	 	—  	  	 	 	1,158,000	  	  	 	—  	  
	 1983-A
	  	 	1,380,331	  	  	 	415,348	  	 	 	—  	  	 	 	819,000	  	  	 	—  	  
	 1984
	  	 	964,713	  	  	 	512,407	  	 	 	(29,802	) 	 	 	1,189,835	  	  	 	—  	  
	 1984 Employee(*)
	  	 	874	  	  	 	1,077	  	 	 	—  	  	 	 	1,000	  	  	 	—  	  
	 1985 Employee(*)
	  	 	2,300	  	  	 	1,288	  	 	 	—  	  	 	 	1,035	  	  	 	—  	  
	 1986 Energy Income Fund(**)
	  	 	211,916	  	  	 	(1,141,062	) 	 	 	(86,147	) 	 	 	473,865	  	  	 	—  	  
	 1986 Employee(*)
	  	 	2,698	  	  	 	5,108	  	 				 	 	4,486	  	  	 	—  	  
	 1987 Employee(*)
	  	 	357,368	  	  	 	548,372	  	 	 	—  	  	 	 	465,800	  	  	 	—  	  
	 1988 Employee(*)
	  	 	770,272	  	  	 	1,161,840	  	 	 	—  	  	 	 	942,800	  	  	 	—  	  
	 1989 Employee(*)
	  	 	1,010,133	  	  	 	752,569	  	 	 	—  	  	 	 	607,900	  	  	 	—  	  
	 1990 Employee(*)
	  	 	466,272	  	  	 	338,281	  	 	 	—  	  	 	 	266,600	  	  	 	—  	  
	 1991 Employee(****)
	  	 	1,056,956	  	  	 	1,750,810	  	 	 	—  	  	 	 	1,618,020	  	  	 	—  	  
	 1992 Employee(****)
	  	 	99,250	  	  	 	258,229	  	 	 	—  	  	 	 	230,839	  	  	 	—  	  
	 1993 Employee(****)
	  	 	311,650	  	  	 	533,059	  	 	 	—  	  	 	 	472,480	  	  	 	—  	  
	 1994 Employee(****)
	  	 	856,390	  	  	 	1,262,097	  	 	 	—  	  	 	 	1,076,708	  	  	 	—  	  
	 1995 Employee(****)
	  	 	330,617	  	  	 	454,020	  	 	 	—  	  	 	 	350,504	  	  	 	—  	  
	 1996 Employee(****)
	  	 	681,656	  	  	 	649,437	  	 	 	—  	  	 	 	450,383	  	  	 	—  	  
	 1997 Employee(****)
	  	 	1,057,002	  	  	 	926,325	  	 	 	—  	  	 	 	695,477	  	  	 	—  	  
	 1998 Employee(****)
	  	 	920,862	  	  	 	824,096	  	 	 	—  	  	 	 	638,218	  	  	 	—  	  
	 1999 Employee(****)
	  	 	706,281	  	  	 	1,067,032	  	 	 	—  	  	 	 	796,578	  	  	 	—  	  
	 Consolidated Program
	  	 	13,792	  	  	 	52,645	  	 	 	(167	) 	 	 	46,647	  	  	 	—  	  
	 2000 Employee
	  	 	1,656,969	  	  	 	3,022,850	  	 	 	25,699	  	 	 	2,336,169	  	  	 	23,000	  
	 2001 Employee
	  	 	877,623	  	  	 	953,367	  	 	 	5,572	  	 	 	792,750	  	  	 	5,000	  
	 2002 Employee
	  	 	937,647	  	  	 	1,509,677	  	 	 	11,138	  	 	 	1,124,500	  	  	 	3,500	  
	 2003 Employee
	  	 	1,591,268	  	  	 	3,428,688	  	 	 	25,088	  	 	 	2,901,750	  	  	 	32,000	  
	 2004 Employee
	  	 	597,018	  	  	 	765,411	  	 	 	4,400	  	 	 	586,300	  	  	 	4,000	  
	 2005 Employee
	  	 	2,164,956	  	  	 	2,134,026	  	 	 	31,998	  	 	 	1,416,500	  	  	 	32,000	  
	 2006 Employee
	  	 	1,940,291	  	  	 	1,388,888	  	 	 	23,619	  	 	 	816,500	  	  	 	27,500	  
	 2007 Employee
	  	 	1,832,643	  	  	 	1,727,612	  	 	 	54,975	  	 	 	1,034,000	  	  	 	43,000	  
	 2008 Employee
	  	 	3,182,525	  	  	 	1,108,505	  	 	 	89,076	  	 	 	263,130	  	  	 	123,000	  
	 2009 Employee
	  	 	1,066,899	  	  	 	223,224	  	 	 	44,381	  	 	 	20,500	  	  	 	20,500	  
	 2010 Employee
	  	 	2,354,042	  	  	 	81,211	  	 	 	71,043	  	 	 	—  	  	  	 	—  	  

  

	(*)	 Effective December 31, 1993, this program was merged with and into the Consolidated Program. 



	(**)	 Formed primarily for purposes of acquiring producing oil and gas properties. 



	(***)	 Effective July 1, 2003, this program was dissolved. 



	(****)	 Effective December 31, 2002 this Program was merged with and into the Consolidated Program. 



  
 48 









 LIMITED PARTNERS’ NET CASH TABLE(1) 

As of September 30, 2010 
  

																									
	 Program
	  	Capital
Contributed	 	 	Total
Capital
Expenditures(2)	 	  	Total
Revenues
Less
Operating
Costs	 	  	Total
Revenues
Less
Operating
Costs for
3 Months
Ended
Sept. 30,
2010	 	  	Total
Revenues
Distributed	 	  	Total
Revenues
Distributed
during the
3 Months
Ended
Sept. 30,
2010	 
	
1979(***)

	  	$	3,000,000	  	 	$	6,085,402	  	  	$	10,194,451	  	  	$	—  	  	  	$	6,198,801	  	  	$	—  	  
	 1980
	  	 	12,000,000	(3) 	 	 	14,469,265	  	  	 	3,729,906	  	  	 	—  	  	  	 	760,000	  	  	 	—  	  
	 1981
	  	 	29,255,000	(4) 	 	 	32,700,741	  	  	 	11,395,621	  	  	 	—  	  	  	 	5,335,065	  	  	 	—  	  
	 1981-II
	  	 	15,000,000	  	 	 	16,603,760	  	  	 	4,994,106	  	  	 	—  	  	  	 	1,710,001	  	  	 	—  	  
	 1982-A
	  	 	21,140,000	  	 	 	21,591,442	  	  	 	9,434,313	  	  	 	—  	  	  	 	6,342,000	  	  	 	—  	  
	 1982-B
	  	 	10,555,000	  	 	 	9,935,850	  	  	 	3,233,596	  	  	 	—  	  	  	 	2,828,740	  	  	 	—  	  
	 1983-A
	  	 	2,530,000	  	 	 	2,993,705	  	  	 	1,145,026	  	  	 	—  	  	  	 	227,700	  	  	 	—  	  
	 1984
	  	 	1,875,000	  	 	 	2,043,942	  	  	 	1,664,347	  	  	 	12,082	  	  	 	1,364,306	  	  	 	—  	(5) 
	 1984 Employee(*)
	  	 	174,000	  	 	 	86,664	  	  	 	137,262	  	  	 	—  	  	  	 	125,280	  	  	 	—  	  
	 1985 Employee(*)
	  	 	283,500	  	 	 	227,670	  	  	 	128,753	  	  	 	—  	  	  	 	182,644	  	  	 	—  	  
	 1986 Energy Income Fund(**)
	  	 	1,000,000	  	 	 	1,040,371	  	  	 	2,473,849	  	  	 	5,869	  	  	 	2,311,500	  	  	 	(6	) 
	 1986 Employee(*)
	  	 	229,750	  	 	 	267,008	  	  	 	508,122	  	  	 	—  	  	  	 	460,007	  	  	 	—  	  
	 1987 Employee(*)
	  	 	209,000	  	 	 	207,060	  	  	 	335,044	  	  	 	—  	  	  	 	324,845	  	  	 	—  	  
	 1988 Employee(*)
	  	 	177,000	  	 	 	214,712	  	  	 	326,858	  	  	 	—  	  	  	 	281,630	  	  	 	—  	  
	 1989 Employee(*)
	  	 	157,000	  	 	 	157,306	  	  	 	153,044	  	  	 	—  	  	  	 	147,737	  	  	 	—  	  
	 1990 Employee(*)
	  	 	253,000	  	 	 	254,483	  	  	 	142,479	  	  	 	—  	  	  	 	180,895	  	  	 	—  	  
	 1991 Employee(****)
	  	 	263,000	  	 	 	275,590	  	  	 	467,325	  	  	 	—  	  	  	 	438,947	  	  	 	—  	  
	 1992 Employee(****)
	  	 	240,000	  	 	 	256,030	  	  	 	667,138	  	  	 	—  	  	  	 	626,888	  	  	 	—  	  
	 1993 Employee(****)
	  	 	245,000	  	 	 	281,201	  	  	 	493,998	  	  	 	—  	  	  	 	459,375	  	  	 	—  	  
	 1994 Employee(****)
	  	 	284,000	  	 	 	345,243	  	  	 	516,980	  	  	 	—  	  	  	 	433,668	  	  	 	—  	  
	 1995 Employee(****)
	  	 	454,000	  	 	 	493,337	  	  	 	672,314	  	  	 	—  	  	  	 	572,524	  	  	 	—  	  
	 1996 Employee(****)
	  	 	437,000	  	 	 	419,615	  	  	 	405,010	  	  	 	—  	  	  	 	382,812	  	  	 	—  	  
	 1997 Employee(****)
	  	 	413,000	  	 	 	495,786	  	  	 	415,402	  	  	 	—  	  	  	 	348,159	  	  	 	—  	  
	 1998 Employee(****)
	  	 	471,000	  	 	 	486,317	  	  	 	423,769	  	  	 	—  	  	  	 	398,937	  	  	 	—  	  
	 1999 Employee(****)
	  	 	141,000	  	 	 	214,376	  	  	 	317,387	  	  	 	—  	  	  	 	288,204	  	  	 	—  	  
	 Consolidated
	  	 	—  	  	 	 	1,278,685	  	  	 	5,229,530	  	  	 	55,321	  	  	 	4,688,820	  	  	 	61,869	(7) 
	 2000 Employee
	  	 	199,000	  	 	 	226,293	  	  	 	409,465	  	  	 	3,513	  	  	 	385,791	  	  	 	3,582	(8) 
	 2001 Employee
	  	 	370,000	  	 	 	394,295	  	  	 	429,094	  	  	 	2,504	  	  	 	398,057	  	  	 	2,960	(9) 
	 2002 Employee
	  	 	457,000	  	 	 	483,029	  	  	 	778,640	  	  	 	5,746	  	  	 	676,934	  	  	 	3,199	(10) 
	 2003 Employee
	  	 	284,000	  	 	 	325,925	  	  	 	703,144	  	  	 	5,143	  	  	 	649,757	  	  	 	6,532	(11) 
	 2004 Employee
	  	 	434,000	  	 	 	488,468	  	  	 	626,660	  	  	 	3,605	  	  	 	564,684	  	  	 	4,340	(12) 
	 2005 Employee
	  	 	496,000	  	 	 	507,830	  	  	 	501,445	  	  	 	7,509	  	  	 	484,130	  	  	 	7,936	(13) 
	 2006 Employee
	  	 	767,000	  	 	 	856,692	  	  	 	627,470	  	  	 	10,613	  	  	 	519,259	  	  	 	22,243	(14) 
	 2007 Employee
	  	 	946,000	  	 	 	1,030,861	  	  	 	974,733	  	  	 	30,932	  	  	 	844,778	  	  	 	29,326	(15) 
	 2008 Employee
	  	 	841,000	  	 	 	897,631	  	  	 	313,917	  	  	 	25,130	  	  	 	220,347	  	  	 	35,322	(16) 
	 2009 Employee
	  	 	391,000	  	 	 	435,775	  	  	 	95,509	  	  	 	18,127	  	  	 	32,453	  	  	 	—  	(17) 
	 2010 Employee
	  	 	485,000	  	 	 	784,681	  	  	 	27,183	  	  	 	23,707	  	  	 	—  	  	  	 	—  	(18) 

  

	(*)	 Effective December 31, 1993, this program was merged with and into the Consolidated Program. 



	(**)	 Formed primarily for purposes of acquiring producing oil and gas properties. 



	(***)	 Effective July 1, 2003, this program was dissolved. 



	(****)	 Effective December 31, 2002 this Program was merged with and into the Consolidated Program. 



  
 49 










	(1)	Amounts reflect the accrual method of accounting. 


	(2)	Does not include expenditures of $237,600, $920,453, $2,252,900, $1,480,248, $2,079,268, $985,371 and $241,076 which were obtained from bank borrowings and used to pay
the limited partners’ share of sales commissions of $237,600, $722,453, $1,940,400, $1,183,248, $1,656,468, $827,046 and $190,476 and organization costs of $—0—, $198,000, $312,500, $297,000, $422,800, $158,325 and $50,600 for the
1979, 1980, 1981, 1981-II, 1982-A, 1982-B and 1983-A Programs, respectively. 


	(3)	Includes original subscriptions of limited partners totaling $10,000,000 and additional assessments totaling $2,000,000. 


	(4)	Includes original subscriptions of limited partners totaling $25,000,000 and additional assessments totaling $4,255,000. 


	(5)	In November 2010 the 1984 Program made a distribution of $11,655 to that program’s limited partners. 


	(6)	In November 2010 the 1986 Program made no distribution to its limited partners. 


	(7)	In November 2010 the Consolidated Employee Program made a distribution of $53,857 to that program’s limited partners. 


	(8)	In November 2010 the 2000 Employee Program made a distribution of $4,179 to that program’s limited partners. 


	(9)	In November 2010 the 2001 Employee Program made a distribution of $2,220 to that program’s limited partners. 


	(10)	In November 2010 the 2002 Employee Program made a distribution of $3,199 to that program’s limited partners. 


	(11)	In November 2010 the 2003 Employee Program made a distribution of $5,396 to that program’s limited partners. 


	(12)	In November 2010 the 2004 Employee Program made a distribution of $2,604 to that program’s limited partners. 


	(13)	In November 2010 the 2005 Employee Program made a distribution of $7,440 to that program’s limited partners. 


	(14)	In November 2010 the 2006 Employee Program made a distribution of $11,505 to that program’s limited partners. 


	(15)	In November 2010 the 2007 Employee Program made a distribution of $25,542 to that program’s limited partners. 


	(16)	In November 2010 the 2008 Employee Program made a distribution of $18,502 to that program’s limited partners. 


	(17)	In November 2010 the 2009 Employee Program made a distribution of $4,301 to that program’s limited partners. 


	(18)	The 2010 Employee Program has made no distributions to its limited partners to date. 


FEDERAL INCOME TAX CONSIDERATIONS 
 The following is a summary of the opinions of Conner & Winters on all material federal income tax consequences to the Partnership and to the Limited Partners. The full tax opinion of
Conner & Winters is attached to this Memorandum as Exhibit B. All prospective investors should review Exhibit B in its entirety before investing in the Partnership. There may be aspects of a particular investor’s tax situation which
are not addressed in the following discussion or in Exhibit B. Additionally, the resolution of certain tax issues depends on future facts and circumstances not known to Conner & Winters as of the date of this Memorandum; thus, no assurance
as to the final resolution of such issues should be drawn from the following discussion. 

  
 50 









 The following statements are based on the provisions of the Code as of the date of this Memorandum, existing
and proposed regulations promulgated under the Code (“Regulations”), current administrative rulings, and court decisions. It is possible that legislative or administrative changes or future court decisions may significantly modify the
statements and opinions expressed herein. Such changes could be retroactive with respect to transactions occurring prior to the date of such changes. 
 Moreover, uncertainty exists concerning some of the federal income tax aspects of the transactions being undertaken by the Partnership. Some of the tax positions being taken by the Partnership may be
challenged by the Service. Thus, there can be no assurance that all of the anticipated tax benefits of an investment in the Partnership will be realized. 
 Conner & Winters’ opinion is based on the transactions described in this Memorandum (the “Transaction”) and on facts as they have been represented to Conner & Winters or
determined by it as of the date of the opinion. Any alteration of the facts could render the conclusions in the opinion inapplicable. 
 Because
of the factual nature of the inquiry, and in certain cases the lack of clear authority in the law, it is not possible to reach a judgment as to the outcome on the merits (either favorable or unfavorable) of certain material federal income tax issues
as described more fully herein. 
 Summary of Conclusions 
 Opinions expressed: The following is a summary of the specific federal income tax opinions rendered by Conner & Winters in Exhibit B. 

1. The material federal income tax benefits in the aggregate from an investment in the Partnership will be realized. 

2. The Partnership will be treated as a partnership for federal income tax purposes and not as a corporation, an association taxable as a corporation or
a “publicly traded partnership”. See “Partnership Status”; “Federal Taxation of Partnerships.” 
 3. To the extent
the Partnership’s wells are timely drilled and its drilling costs are timely paid, the Partners will be entitled to their pro rata shares of the Partnership’s intangible drilling and development costs (“IDC”) paid in 2011. See
“Intangible Drilling and Development Costs Deductions.” 
 4. Most Limited Partners’ Units will be considered as ownership
interests in a passive activity within the meaning of Code Section 469 and losses generated therefrom will be limited by the passive activity provisions of the Code. See “Passive Loss and Credit Limitations.” 

5. To the extent provided in such opinion, the Partners’ distributive shares of Partnership tax items will be determined and allocated substantially
in accordance with the terms of the Partnership Agreement. See “Partnership Allocations.” 
 No opinion expressed: Due
to the lack of authority regarding, or the essentially factual nature of, the issue, Conner & Winters expresses no opinion as to: 
 1.
The impact of an investment in the Partnership on an investor’s alternative minimum tax liability; 
 2. Whether each Partner will be
entitled to percentage depletion since such a determination is dependent on the status of the Partner as an independent producer and on the Partner’s other oil and gas production (See “Depletion Deductions”); 

3. Whether the Partnership will be treated as the tax owner of Partnership Properties acquired by the General Partner as nominee for the Partnership.

 Facts and Representations: In rendering its opinion, Conner & Winters relied on certain representations made to it by
the General Partner, including the following: 
 1. The Partnership Agreement to be entered into by and among the General Partner and Limited
Partners and any amendments thereto will be duly executed and will be made available to any Limited Partner on written request. A certificate of limited partnership will be duly recorded in all places required under the Oklahoma


  
 51 









 
Uniform Limited Partnership Act of 2010 (the “Act”) for the due formation of the Partnership and for the continuation thereof in accordance with the terms of the Partnership Agreement.
The Partnership will at all times be operated in accordance with the terms of the Partnership Agreement, this Memorandum, and the Act. 
 2. No
election will be made by the Partnership, Limited Partners, or General Partner to be excluded from the application of the provisions of Subchapter K of the Code. 
 3. The Partnership will own operating mineral interests, as defined in the Code and in the Regulations, and none of the Partnership’s revenues will be from non-working interests. 

4. The General Partner will cause the Partnership to elect to deduct currently all IDC in the manner required by the Code and Regulations. 

5. The Partnership will have a December 31 taxable year and will report its income on the accrual basis. 

6. All Partnership wells will be spudded no later than December 31, 2011. The entire amount to be paid under any drilling and operating agreements
entered into by the Partnership will be attributable to IDC. 
 7. Such drilling and operating agreements will be duly executed and will govern
the operation of the Partnership’s wells. 
 8. The General Partner believes that at least 90% of the gross income of the Partnership will
constitute income derived from the exploration, development, production, and/or marketing of oil and gas. The General Partner does not believe that any market will ever exist for the sale of Units and the General Partner will not make a market for
the Units. Further, the Units will not be traded on an established securities market. 
 9. The Partnership and each Partner will have the
objective of carrying on the business of the Partnership for profit and dividing the gain therefrom. 
 10. The General Partner will, as nominee
for the Partnership, acquire and hold title to Partnership Properties on behalf of the Partnership; the General Partner will enter into an agency agreement before the General Partner acquires any such oil and gas properties on behalf of the
Partnership; the agency agreement will reflect that the General Partner’s acquisition of Partnership properties is on behalf of the Partnership; and the General Partner will execute assignments of all oil and gas interests acquired by it on
behalf of the Partnership to the Partnership. 
 The opinions of Conner & Winters are also subject to all the assumptions,
qualifications, and limitations set forth in the following discussion and in the opinion, including the assumptions that each of the Partners has full power, authority, and legal right to enter into and perform his or her obligations under the terms
of the Partnership Agreement and to take any and all actions thereunder in connection with the transactions contemplated thereby. 
 Each
prospective investor should be aware that, unlike a ruling from the Service, an opinion of Conner & Winters represents only Conner & Winters’ best judgment. THERE CAN BE NO ASSURANCE THAT THE SERVICE WILL NOT SUCCESSFULLY
ASSERT POSITIONS WHICH ARE INCONSISTENT WITH THE OPINIONS OF CONNER & WINTERS SET FORTH IN THIS DISCUSSION AND EXHIBIT B OR IN THE TAX REPORTING POSITIONS TAKEN BY THE PARTNERS OR THE PARTNERSHIP. EACH PROSPECTIVE INVESTOR SHOULD CONSULT
HIS OR HER OWN TAX ADVISOR TO DETERMINE THE EFFECT OF THE TAX ISSUES DISCUSSED HEREIN AND IN EXHIBIT B ON HIS OR HER INDIVIDUAL TAX SITUATION. 
 Compliance with Circular 230: The United States Treasury Department establishes standards for tax practitioners who practice before the Internal Revenue Service (the “Service”).
Those standards are set forth in a publication known as Circular 230. Circular 230 requires that written statements issued by a tax practitioner that constitute “Covered Opinions” contain certain material and conform to a specific manner
of presentation. Additionally, Circular 230 requires that other written advice issued by a tax practitioner that does not constitute a Covered Opinion satisfy certain “reasonableness” standards with respect to representations and factual
and legal assumptions. Neither this summary discussion nor the tax opinion of Conner & Winters attached to the Memorandum as Exhibit B constitutes a Covered Opinion within the meaning of Circular 230. This summary discussion is drafted in a
manner designed to comply with the requirements of Circular 230 with respect to the reasonableness standards for other written advice. 

  
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 IMPORTANT LIMITATIONS ON SUMMARY AND TAX OPINION 

Neither this summary discussion nor the tax opinion of Conner & Winters attached to the Memorandum as Exhibit B was intended or written to be
used, and neither may be used, for the purpose of avoiding penalties that may be imposed by the Service. This summary discussion and the tax opinion of Conner & Winters were written to support the promotion or marketing of Units in the
Partnership. Prospective investors should seek advice based on their particular circumstances from an independent tax advisor. 

General Tax Effects of Partnership Structure 
 The Partnership will be formed as a limited partnership pursuant to the Partnership Agreement and the laws of the State of Oklahoma. No tax ruling will be sought from the Service as to the status of the
Partnership as a partnership for federal income tax purposes. The applicability of the federal income tax consequences described herein depends on the treatment of the Partnership as a partnership for federal income tax purposes and not as a
corporation and not as an association taxable as a corporation. Any tax benefits anticipated from an investment in the Partnership would be adversely affected or eliminated if the Partnership were treated as a corporation for federal income tax
purposes. 
 Conner & Winters is of the opinion that, at the time of its formation, the Partnership will be treated as a partnership
for federal income tax purposes. The opinion is based on the provisions of the Partnership Agreement, applicable state and federal law and representations made by the General Partner 
 Under the Code, a partnership is not a taxable entity and, accordingly, incurs no federal income tax liability. Rather, a partnership is a “pass-through” entity which is required to file an
information income tax return with the Service. In general, the character of a partner’s share of each item of income, gain, loss, deduction, and credit is determined at the partnership level. Each partner is allocated a distributive share of
such items in accordance with the partnership agreement. Each partner is required to include such amounts in determining his or her income for any taxable year of the partnership ending within or with the taxable year of the partner, without regard
to whether the partner has received or will receive any cash distributions from the partnership. 
 Ownership of Partnership Properties

 The General Partner, as nominee for the Partnership (the “Nominee”), will acquire and hold title to Partnership Properties
on behalf of the Partnership. The Nominee and the Partnership will enter into an agency agreement before the Nominee acquires any oil and gas properties on behalf of the Partnership. That agency agreement will reflect that the Nominee’s
acquisition of Partnership Properties is on behalf of the Partnership. The Nominee will execute assignments of all oil and gas interest acquired by the Nominee on behalf of the Partnership to the Partnership. For various cost and procedural reasons,
the assignments will not be recorded in the real estate records in the counties in which the Partnership Properties are located. That is, while the Partnership will be the owner of the Partnership Properties, there will be no public record of that
ownership. It is possible that the Service could assert that the Nominee should be treated for federal income tax purposes as the owner of the Partnership Properties, notwithstanding the assignment of those Partnership Properties to the Partnership.
If the Service were to argue successfully that the Nominee should be treated as the tax owner of the Partnership Properties, there would be significant adverse federal income tax consequences to the Limited Partners, such as the unavailability of
depletion deductions in respect of income from Partnership Properties. The Service is concerned that taxpayers not shift the tax consequences of transactions between parties based on the parties’ declaration that one party is the agent of
another and the Service generally requires that taxpayers respect the form of their transactions and ownership of property. Based on this concern, the Service may challenge the Partnership’s treatment of Partnership Properties, and tax
attributes thereof, which are held of record by the Nominee. 
 In Commissioner of Internal Revenue v. Bollinger, 485 U.S. 340 (1988),
the United States Supreme Court reviewed a principal-agent relationship and held for the taxpayer in concluding that the principal should be treated as the tax owner of property held in the name of the agent. In that case the Supreme Court noted
that “It seems to us that the genuineness of the agency relationship is adequately assured, and tax-avoiding manipulation adequately avoided, when the fact that the corporation is acting as agent for its shareholders with respect to a


  
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particular asset is set forth in a written agreement at the time the asset is acquired, the corporation functions as agent and not principal with respect to the asset for all purposes, and the
corporation is held out as the agent and not principal in all dealings with third parties relating to the asset.” While the Partnership and the Nominee will have in place an agreement defining their relationship before any Partnership
Properties are acquired by the Nominee and the Nominee will function as agent with respect to those Partnership Properties on behalf of the Partnership, the Nominee will not hold itself out to all third parties as the agent of the Partnership in
dealings relating to the Partnership Properties. Unlike the relationship between the principal and the agent in Bollinger, the Nominee will, however, assign title to Partnership Properties to the Partnership, but will not record those
assignments. Accordingly, the facts related to the relationship between the Nominee and the Partnership are not the same as the facts in Bollinger and it is not clear that the failure of the Nominee to hold itself out to third parties as the
agent of the Partnership in dealings relating to Partnership Properties should result in the treatment of the Nominee as the tax owner of the Partnership Properties. For the foregoing reasons, Conner & Winters has not expressed an opinion
on this issue, but Conner & Winters believes that substantial arguments may be made that the Partnership should be treated as the tax owner of Partnership Properties acquired by the Nominee on the Partnership’s behalf. If the
Partnership were not treated as the tax owner of Partnership Properties, then the following discussions which relate to the Partners’ deduction of tax items which are derived from Partnership Properties, such as IDC, depletion and depreciation,
would not be applicable. 
 Intangible Drilling and Development Costs Deductions 

The Secretary of the Treasury has prescribed regulations that allow taxpayers the option of deducting, rather than capitalizing, IDC. The Secretary’s
rules state that, in general, the option to deduct IDC applies only to expenditures for drilling and development items that do not have a salvage value. 
 Most of the Partners’ capital contributions will be utilized for IDC, which will flow through to the Partners as a deductible item in the year of investment. The deduction of IDC by most Limited
Partners generally will be available only to offset passive income. 
 Classification of Costs. In general, IDC consists of those
costs which in and of themselves have no salvage value. In previous partnerships for which the General Partner has served as general partner, intangible drilling and development costs have ranged from one-quarter to three-quarters of the
investors’ contributions. While the planned activities of the Partnership are similar in nature to those of prior partnerships, the amount of expenditures classified as IDC could be greater or less than for prior partnerships. In addition, a
partnership’s classification of a cost as IDC is not binding on the Service, which might reclassify an item labeled as IDC as a cost which must be capitalized. To the extent an expenditure is not deductible, such expenditure will be included in
the Partnership’s basis in a mineral property and in the Partners’ tax basis in their interests in the Partnership. 
 Timing of
Deductions. Although the Partnership will elect to deduct IDC, each investor has an option of deducting IDC, or capitalizing all or a part of the IDC and amortizing it on a straight-line basis over a sixty-month period, beginning with the
taxable month in which the expenditure is made. In addition to the effect an investor’s choice will have on regular taxable income, the two methods have different treatment under the Alternative Minimum Tax. 

Although the General Partner will attempt to satisfy each requirement for deductibility of the Partnership’s IDC in 2011, no assurance can be given
that the Service will not successfully contend that the IDC of a Partnership well which is not completed until 2012 is not deductible in whole or in part until 2012. Furthermore, no assurance can be given that the Service will not challenge the
current deduction of IDC because of the prepayment being made to a related party. If the Service were successful with such a challenge, some portion of the Partners’ deductions for IDC would be deferred to later years. 

Recapture of IDC. IDC previously deducted that is allocable to a property (directly or through the ownership of an interest in a
partnership) and which, if capitalized, would have been included in the adjusted basis of the property is recaptured as ordinary income to the extent of any gain realized on the disposition of the property. Regulations provide that recapture is
determined at the partner level (subject to certain anti-abuse provisions). Where only a portion of recapture property is disposed of, any IDC related to the entire property is recaptured to the extent of the gain realized on the portion of the
property sold. In the case of the disposition of an undivided interest in a property (as opposed to the disposition of a portion of the property), a proportionate part of the IDC with respect to the property is treated as allocable to the
transferred undivided interest to the extent of any realized gain. 

  
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 Depletion Deductions 
 The owner of an economic interest in an oil and gas property is entitled to claim the greater of percentage depletion or cost depletion with respect to oil and gas properties which qualify for such
depletion methods. In the case of partnerships, the depletion allowance must be computed separately by each partner and not by the partnership. For properties placed in service after 1986, depletion deductions, to the extent they reduce basis in an
oil and gas property, are subject to recapture under Code section 1254. 
 Cost depletion for any year is determined by multiplying the number
of units (e.g., barrels of oil or Mcf of gas) sold during the year by a fraction, the numerator of which is the cost or other basis of the mineral interest and the denominator of which is total reserves available at the beginning of the period. In
no event can the cost depletion exceed the adjusted basis of the property to which it relates. 
 Percentage depletion is a statutory allowance
pursuant to which a deduction currently equal to 15% of the taxpayer’s gross income from each property is allowed in any taxable year, not to exceed 100% of the taxpayer’s taxable income from the property (computed without the allowance
for depletion) with the aggregate deduction limited to 65% of the taxpayer’s taxable income for the year (computed without regard to percentage depletion and net operating loss and capital loss carrybacks). A percentage depletion deduction that
is disallowed in a year due to the 65% of taxable income limitation may be carried forward and allowed as a deduction for a subsequent year, subject to the 65% limitation in that subsequent year. Percentage depletion deductions reduce the
taxpayer’s adjusted basis in the property. However, unlike cost depletion, percentage depletion deductions are not limited to the adjusted basis of the property; the percentage depletion amount continues to be allowable as a deduction after the
adjusted basis has been reduced to zero. 
 The availability of depletion, whether cost or percentage, will be determined separately by each
Partner. Each Partner must separately keep records of his share of the adjusted basis in an oil or gas property, adjust such share of the adjusted basis for any depletion taken on such property, and use such adjusted basis each year in the
computation of his cost depletion or in the computation of his gain or loss on the disposition of such property. These requirements may place an administrative burden on a Partner. 
 Production Activities Deduction 
 The Partnership will be eligible for the deduction
available for qualified production activities. The deduction will be applied at the Partner level (as a deduction from adjusted gross income for an individual) based on allocations to Partners of their shares of the Partnership’s qualified
production activities income. Qualified production activities income for the Partnership will include its oil and gas production gross receipts reduced by the sum of the cost of goods sold allocable to such receipts, other deductions, expenses and
losses directly allocable to such receipts, and a ratable portion of other deductions and expenses not directly allocable to such receipts or any other class of income of the Partnership. The deduction rate is 9 percent. The amount of the deduction
allowable for any taxable year may not exceed 50 percent of the W-2 wages of the taxpayer for the year (in the case of a Partner, the Partner’s allocable share of the Partnership’s W-2 wages). 

Depreciation Deductions 
 The
Partnership will claim depreciation, cost recovery, and amortization deductions with respect to its basis in Partnership Property as permitted by the Code. 
 Transaction Fees 
 The Partnership may classify a portion of the fees or expense
reimbursements to be paid to third parties and to the General Partner as expenses which are deductible as organizational expenses or otherwise. There is no assurance that the Service will allow the deductibility of such expenses and
Conner & Winters expresses no opinion with respect to the allocation of such fees or reimbursements to deductible and nondeductible items. 

  
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 Generally, expenditures made in connection with the creation of, and with sales of interests in, a
partnership will fit within one of several categories. 
 For the taxable year in which it begins business the Partnership may elect to deduct
its organizational expenses (as defined in Code Section 709(b)(2) and in Reg. Section 1.709-2(a)) in an amount equal to the lesser of (i) the amount of the organizational expenses, or (ii) $5,000, reduced (but not below zero) by
the amount by which such organizational expenses exceed $50,000. The remainder of the Partnership’s organizational expenses will be allowable as a deduction ratably over the 180-month period beginning with the month in which the Partnership
begins business. Examples of organizational expenses are legal fees for services incident to the organization of the partnership, such as negotiation and preparation of a partnership agreement, accounting fees for services incident to the
organization of the partnership, and filing fees. 
 No deduction is allowable for “syndication expenses,” examples of which include
brokerage fees, registration fees, legal fees of the underwriter or placement agent and the issuer (general partners or the partnership) for securities advice and for advice pertaining to the adequacy of tax disclosures in the offering or private
placement memorandum for securities law purposes, printing costs, and other selling or promotional material. These costs must be capitalized. Payments for services performed in connection with the acquisition of capital assets must be amortized over
the useful life of such assets. 
 Under Code Section 195, for the taxable year in which a taxpayer’s active trade or business begins,
the taxpayer may elect to deduct its start-up expenditures in an amount equal to the lesser of (i) the amount of the start-up expenditures, or (ii) $5,000, reduced (but not below zero) by the amount by which such start-up expenditures
exceed $50,000. The remainder of the taxpayer’s start-up expenditures will be allowable as a deduction ratably over the 180-month period beginning with the month in which the active trade or business begins. 

The Partnership intends to make overhead reimbursement payments to the General Partner, as described in greater detail in the Memorandum. To be
deductible, payments to a partner must be for services rendered by the partner other than in his or its capacity as a partner or for compensation determined without regard to partnership income. Payments which are not deductible because they fail to
meet this test may be treated as special allocations of income to the recipient partner and thereby decrease the net loss, or increase the net income among all partners. If the Service were to successfully challenge the General Partner’s
allocations, a Partner’s taxable income could be increased, thereby resulting in increased taxes and in potential liability for interest and penalties. 
 Basis and At Risk Limitations 
 A Partner’s share of Partnership losses will be
allowed as a deduction by the Partner only to the extent of the aggregate amount with respect to which the taxpayer-Partner is “at risk” for the Partnership’s activity at the close of the taxable year. Any such loss disallowed by the
“at risk” limitation is treated as a deduction allocable to the activity in the first succeeding taxable year. 
 The Code provides
that a taxpayer must recognize taxable income to the extent that his or her “at risk” amount is reduced below zero. This “recaptured” income is limited to the sum of the loss deductions previously allowed to the taxpayer, less
any amounts previously recaptured. A taxpayer may be allowed a deduction for the recaptured amounts included in his taxable income if and when he increases his amount “at risk” in a subsequent taxable year. 

The Limited Partners will purchase Units by tendering cash to the Partnership. To the extent the cash contributed constitutes the “personal
funds” of the Partners, the Partners should be considered at risk with respect to those amounts. If the cash contributed constitutes “personal funds”, neither the at risk rules nor the adjusted basis rules will limit the deductibility
of losses generated from the Partnership and allocated to a Limited Partner, to the extent of such Limited Partner’s cash contributions. In no event, however, may a Partner deduct his distributive share of partnership loss to the extent such
share exceeds the Partner’s tax basis in the Partnership. 
 Passive Loss Limitations 

The deductibility of losses generated from passive activities is limited for certain taxpayers. The passive activity loss limitations apply to
individuals, estates, trusts, and personal service corporations as well as, to a lesser extent, closely held C corporations. 

  
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 The definition of a “passive activity” generally encompasses all rental activities as well as all
activities with respect to which the taxpayer does not “materially participate.” A taxpayer will be considered as materially participating in a venture only if the taxpayer is involved in the operations of the activity on a “regular,
continuous, and substantial” basis. In addition, no limited partnership interest will be treated as an interest with respect to which a taxpayer materially participates. 
 Passive activity losses (“PALs”) of a taxpayer are the amounts of such taxpayer’s losses from passive activities for a taxable year. Individuals and personal service corporations are
entitled to deduct PALs only to the extent of their passive income whereas closely held C corporations (other than personal service corporations) can offset PALs against both passive and net active income, but not against portfolio (dividends,
interest, etc.) income. In calculating passive income and loss, however, all passive activities of the taxpayer are aggregated. PALs disallowed as a result of the above rules are suspended and may be carried forward indefinitely to offset future
passive (or passive and active, in the case of a closely held C corporation) income. 
 On a taxpayer’s disposition of his entire interest
in a passive activity in a fully taxable transaction not involving a related party, any passive loss of such taxpayer that was suspended by the provisions of the passive activity loss rules is deductible against either passive or non-passive income.

 Most Limited Partners’ shares of the Partnership’s losses will be treated as PALs, the availability of which will be limited in
each case to the individual Partner’s passive income in all passive activities in which the Partner has an interest. If a Limited Partner does not have sufficient passive income to utilize the PALs, the disallowed PALs will be suspended and may
be carried forward to be deducted against passive income arising in future years. Further, on the disposition by a Limited Partner of his entire interest in the Partnership to an unrelated party in a fully taxable transaction, such suspended losses
will be available, as described above. 
 Gain or Loss on Sale of Partnership Property 

In the event some or all of the property of the Partnership is sold, a Limited Partner will be allocated his or her share of the Partnership’s gain
or loss. If the Partnership realizes a gain, there may be recapture, as ordinary income, of IDCs and depletion previously allocated to such Limited Partner. If the gain realized exceeds the amount of the recapture income, the Limited Partner will
recognize capital gains for the balance. 
 It is possible that a Limited Partner will be required to recognize ordinary income pursuant to the
recapture rules in excess of the taxable income on the disposition transaction or in a situation where the disposition transaction resulted in a taxable loss. To balance the excess income, the Limited Partner would recognize a capital loss for the
difference between the gain and the income. Depending on a Limited Partner’s particular tax situation, some or all of this loss might be deferred to future years, resulting in a greater tax liability in the year in which the sale was made and a
reduced future tax liability. 
 Tax Rates. The maximum ordinary income tax rate for individuals is 35% (but
such rate is scheduled to increase to 39.6% for taxable years beginning after December 31, 2012. In general, the maximum individual income tax rate for “Qualified
Dividends”[1] and long-term capital gains is 15%
(unless the taxpayer elects to be taxed at ordinary rates as provided in the Code). However, for taxable years beginning after December 31, 2012, generally the maximum individual rates will be 20% for long-term capital gains and 39.6% for
dividends. The excess of capital losses over capital gains may be offset against the ordinary income of an individual taxpayer, subject to an annual deduction limitation of U.S. $3,000. Capital losses of an individual taxpayer may
generally be carried forward to succeeding tax years to offset capital gains and then ordinary income (subject to the U.S. $3,000 annual limitation). For corporate taxpayers, the maximum income tax rate is 35%. Capital losses of a
corporate taxpayer may be offset only against capital gains, but unused capital losses may be carried back three years (subject to certain limitations) and carried forward five years. 

 

	[1]	 A “Qualified Dividend” is generally a dividend from certain domestic corporations, and from certain foreign corporations that are
either eligible for the benefits of a comprehensive income tax treaty with the United States or are readily tradable on an established securities market in the United States. Shares must be held for certain holding periods in order for a
dividend thereon to be a Qualified Dividend. 



  
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 For taxable years beginning after December 31, 2012, an individual or estate, or a trust that does not
fall into a special class of trusts that is exempt from such tax, will be subject to a 3.8% tax on the lesser of (1) the taxpayer’s “net investment income” for the relevant taxable year and (2) the excess of the
taxpayer’s modified gross income for the taxable year over a certain threshold (which, in the case of individuals, will be between $125,000 and $250,000 depending on the individual’s circumstances). A taxpayer’s “net investment
income” may generally include, among other items, certain interest, dividends, gain, and other types of income from investments, minus the allowable deductions that are properly allocable to that gross income or net gain. A prospective investor
that is an individual, estate or trust should consult its tax advisor regarding the applicability of the Medicare tax to allocations of income and gain from the Partnership to a Limited Partner. 

New Legislation Regarding Medicare Tax. For taxable years beginning after December 31, 2012, an individual or estate, or a trust that does
not fall into a special class of trusts that is exempt from such tax, will be subject to a 3.8% tax on the lesser of (1) the taxpayer’s “net investment income” for the relevant taxable year and (2) the excess of the
taxpayer’s modified gross income for the taxable year over a certain threshold (which, in the case of individuals, will be between $125,000 and $250,000 depending on the individual’s circumstances). A taxpayer’s “net investment
income” may generally include, among other items, certain interest, dividends, gain, and other types of income from investments, minus the allowable deductions that are properly allocable to that gross income or net gain. A prospective investor
that is an individual, estate or trust should consult its tax advisor regarding the applicability of the Medicare tax to allocations of income and gain from the Partnership to a Limited Partner. 

Disposition of Units 

Recognition of Gain or Loss. Gain or loss will be recognized on a sale of Units equal to the difference between the amount realized and the
Limited Partner’s tax basis for the Units sold. A Limited Partner’s amount realized will be measured by the sum of the cash or the fair market value of other property received by him plus his share of the Partnership’s nonrecourse
liabilities. Because the amount realized includes a Limited Partner’s share of the Partnership’s nonrecourse liabilities, the gain recognized on the sale of Units could result in a tax liability in excess of any cash received from the
sale. 
 Prior distributions from the Partnership in excess of cumulative net taxable income for a Unit that decreased a Limited Partner’s
tax basis in that Unit will, in effect, become taxable income if the Unit is sold at a price greater than the Limited Partner’s tax basis in that Unit, even if the price received is less than his original cost. 

Except as noted below, gain or loss recognized by a Limited Partner, other than a “dealer” in Units, on the sale or exchange of a Unit held for
more than one year will generally be taxable as capital gain or loss. However, a portion, which will likely be substantial, of this gain or loss will be separately computed and taxed as ordinary income or loss under Section 751 of the Internal
Revenue Code to the extent attributable to assets giving rise to depreciation recapture or other “unrealized receivables” or to “inventory items” the Partnership own. The term “unrealized receivables” includes potential
recapture items, including depreciation recapture. Ordinary income attributable to unrealized receivables, substantially appreciated inventory items and depreciation recapture may exceed net taxable gain realized upon the sale of a Unit and may be
recognized even if there is a net taxable loss realized on the sale of a Unit. Thus, a Limited Partner may recognize both ordinary income and a capital loss upon a sale of Units. Net capital losses may offset capital gains and no more than $3,000 of
ordinary income, in the case of individuals, and may only be used to offset capital gains in the case of corporations. 
 Notification
Requirements. A Limited Partner who sells any of his Units is generally required to notify the Partnership in writing of that sale within 30 days after the sale, or if earlier, January 15 of the year following the sale. A purchaser of
Units who purchases Units from another Limited Partner is also generally required to notify the Partnership in writing of that purchase within 30 days after the purchase. Upon receiving such notifications, the Partnership is required to notify the
IRS of that transaction and to furnish specified information to the transferor and transferee. Failure to notify the Partnership of a purchase may lead to the imposition of substantial penalties. 

  
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 Partnership Distributions 
 Under the Code, any increase in a partner’s share of partnership liabilities, or any increase in such partner’s individual liabilities by reason of an assumption by him or her of partnership
liabilities is considered to be a contribution of money by the partner to the partnership. Similarly, any decrease in a partner’s share of partnership liabilities or any decrease in such partner’s individual liabilities by reason of the
partnership’s assumption of such individual liabilities will be considered as a distribution of money to the partner by the partnership. 

A Partner’s adjusted basis in his or her Units will initially consist of the cash he or she contributes to the Partnership. His or her basis will be
increased by his or her share of Partnership income and decreased by his or her share of Partnership losses and distributions. To the extent that distributions are in excess of a Partner’s adjusted basis in his or her Partnership interest
(after adjustment for contributions and his or her share of income and losses of the Partnership), that excess will generally be treated as gain from the sale of a capital asset. In addition, gain could be recognized to a distributee partner on the
disproportionate distribution to a partner of unrealized receivables or substantially appreciated inventory. 
 Partnership Allocations

 The Partners’ distributive shares of Partnership income, gain, loss, and deduction should be determined and allocated
substantially in accordance with the terms of the Partnership Agreement. 
 The Service could contend that the allocations contained in the
Partnership Agreement do not have substantial economic effect or are not in accordance with the Partners’ interests in the Partnership and may seek to reallocate these items in a manner that will increase the income or gain or decrease the
deductions allocable to a Partner. 
 Alternative Minimum Tax. Each Limited Partner will be required to take into account his
distributive share of any items of Partnership income, gain, loss or deduction for purposes of the alternative minimum tax. The current minimum tax rate for noncorporate taxpayers is 26% on the first $175,000 of alternative minimum taxable income in
excess of the exemption amount and 28% on any additional alternative minimum taxable income. Prospective Limited Partners are urged to consult with their tax advisors as to the impact of an investment in units on their liability for the alternative
minimum tax. 
 Administrative Matters 
 Returns and Audits. 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 Service. Any such audit may lead to adjustments, in which event the Limited Partners may be required to file amended personal federal income tax returns. Any such audit may also lead to an
audit of a Limited Partner’s individual tax return and adjustments to items unrelated to an investment in Units. 
 For purposes of
reporting, audit, and assessment of additional federal income tax, the tax treatment of “partnership items” is determined at the partnership level. Partnership items include those items that the Regulations provide are more appropriately
determined at the partnership level than the partner level. The Service 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 Service at the partnership level. Individual partners are entitled to notice of such administrative proceedings and decisions therein, except in the case of partners with less than 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 Service also must mail notice to a partner appointed by that group to receive notice. All partners, whether
or not entitled to notice, are entitled to participate in the administrative proceedings at the partnership level, although the Partnership Agreement provides for waiver of certain of these rights by the Limited Partners. All Partners, including
those not entitled to notice, may be bound by a settlement reached by the Partnership’s representative, the “tax matters partner,” which will be Unit Petroleum Company. If a proposed tax deficiency is contested in any court by any
Partner or by the General Partner, all Partners may be deemed parties to such litigation and bound by the result reached therein. 

Consistency Requirements. A partner must generally treat partnership items on his or her federal income tax returns consistently with the
treatment of such items on the partnership information return unless he or she files a statement with the Service identifying the inconsistency or otherwise satisfies the requirements for waiver of the


  
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consistency requirement. Failure to satisfy this requirement will result in an adjustment to conform the 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 a partner to substantial penalties. 

Accuracy-Related Penalties. An additional tax equal to 20% of the amount of any portion of an underpayment of tax that is attributable to
one or more specified causes, including negligence or disregard of rules or regulations, substantial understatements of income tax and substantial valuation misstatements, is imposed by the Internal Revenue Code. No penalty will be imposed, however,
for any portion of an underpayment if it is shown that there was a reasonable cause for that portion and that the taxpayer acted in good faith regarding that portion. 
 For individuals, a substantial understatement of income tax in any taxable year exists if the amount of the understatement exceeds the greater of 10% of the tax required to be shown on the return for the
taxable year or $5,000 ($10,000 for most corporations). The amount of any understatement subject to penalty generally is reduced if any portion is attributable to a position adopted on the return: 

 

	 	(1)	for which there is, or was, “substantial authority”; or 

  

	 	(2)	as to which there is a reasonable basis and the pertinent facts of that position are disclosed on the return. 


If any item of income, gain, loss or deduction included in the distributive shares of the Limited Partners might result in that kind of an
“understatement” of income for which no “substantial authority” exists, the Partnership must disclose the pertinent facts on its return. In addition, the Partnership will make a reasonable effort to furnish sufficient information
for the Limited Partners to make adequate disclosure on their returns and to take other actions as may be appropriate to permit them to avoid liability for this penalty. More stringent rules would apply to “tax shelters,” which the
Partnership does not believe includes it. 
 For individuals, a substantial valuation misstatement exists if the value of any property, or the
adjusted basis of any property, claimed on a tax return is 150% or more of the amount determined to be the correct amount of the valuation or adjusted basis. No penalty is imposed unless the portion of the underpayment attributable to a substantial
valuation misstatement exceeds $5,000 ($10,000 for most corporations). If the valuation or adjusted basis claimed on a return is 200% or more than the correct valuation or adjusted basis, the penalty imposed increases to 40%. The Partnership does
not anticipate making any valuation misstatements. 
 Reportable Transactions. If the Partnership were to engage in a
“reportable transaction,” it (and possibly the Limited Partners and others) would be required to make a detailed disclosure of the transaction to the IRS. A transaction may be a reportable transaction based upon any of several factors,
including the fact that it is a type of tax avoidance transaction publicly identified by the IRS as a “listed transaction” or that it produces certain kinds of losses for partnerships, individuals, S corporations, and trusts in excess of
$2 million in any single year or $4 million in any combination of 6 successive tax years. The Partnership’s participation in a reportable transaction could increase the likelihood that its federal income tax information return (and possibly our
Limited Partners’ tax returns) would be audited by the IRS. Please read “— Information Returns and Audit Procedures.” 

Moreover, if the Partnership were to participate in a reportable transaction with a significant purpose to avoid or evade tax, or in any listed
transaction, the Limited Partners may be subject to the following provisions of the American Jobs Creation Act of 2004: 
  

	 	•	 	 accuracy-related penalties with a broader scope, significantly narrower exceptions, and potentially greater amounts than described above at
“— Accuracy-Related Penalties;” 


  

	 	•	 	 for those persons otherwise entitled to deduct interest on federal tax deficiencies, non-deductibility of interest on any resulting tax liability; and



  

	 	•	 	 in the case of a listed transaction, an extended statute of limitations. 


 The Partnership does not expect to engage in any “reportable transactions.” 

Accounting Methods and Periods 

The Partnership will use the accrual method of accounting and will select the calendar year as its taxable year. 

  
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 State and Local Taxes 
 The opinions expressed herein are limited to issues of federal income tax law and do not address issues of state or local law. Prospective investors are urged to consult their tax advisors regarding the
impact of state and local laws on an investment in the Partnership. 
 COMPETITION, MARKETS AND REGULATION 

The oil and gas industry is highly competitive in all its phases. The Partnership will encounter strong competition from both major independent oil
companies and individuals, many of which possess substantial financial resources, in acquiring economically desirable prospects and equipment and labor to operate and maintain Partnership Properties. There are likewise numerous companies and
individuals engaged in the organization and conduct of oil and gas drilling programs and there is a high degree of competition among such companies and individuals in the offering of their programs. 

Marketing of Production 
 The
availability of a ready market for any oil and gas produced from Partnership Wells will depend on numerous factors beyond the control of the Partnership, including the extent of domestic production and importation of oil and gas, general national
and worldwide economic conditions, the proximity of Partnership Wells to oil and gas pipelines and the capacity available on such oil and gas pipelines, the marketing of other competitive fuels, fluctuation in demand, governmental regulation of
production, refining and transportation, and the pricing, use and allocation of oil and gas and their substitute fuels, and the volatility of spot prices and commodity markets for oil and gas. 

In the event the Partnership acquires an interest in a gas well or completes a productive gas well, or a well that produces both oil and gas, the well
may be shut in for a substantial period of time for lack of a market if the well is in an area distant from existing gas pipelines. The well may remain shut in until such time as a gas pipeline, with available capacity, is extended to such an area
or until such time as sufficient wells are drilled to establish adequate reserves which would justify the construction of a gas pipeline, processing facilities, if necessary, and a transmission system. 

The worldwide supply of oil has been largely dependent on rates of production of foreign reserves. Imports of foreign oil continue to increase. Future
domestic oil prices generally will follow foreign prices which in turn will depend largely on the actions of foreign producers with respect to rates of production and it is virtually impossible to predict what actions those producers will take in
the future. Prices may also be affected by political and other factors relating to the Middle East, Far East and Russia. As a result, it is possible that prices for oil, if any, produced from a Partnership Well will be lower than those currently
available or projected at the time the interest therein is acquired. In addition, production from a new oil well may be delayed or reduced depending on the proximity of and the amount of capacity available on oil pipelines. 

In view of the many uncertainties affecting the supply and demand for crude oil and natural gas, and the change in the makeup of the Congress of the
United States and the resulting potential for a different focus for the United States energy policy, the General Partner is unable to predict what future gas and oil prices will be. 
 Regulation of Partnership Operations 
 Production of any oil and gas found by the
Partnership will be affected by state and federal regulations. All states in which the Partnership intends to conduct activities have statutory provisions regulating the production and sale of oil and gas. Such statutes, and the regulations
promulgated in connection therewith, generally are intended to prevent waste of oil and gas and to protect correlative rights and the opportunities to produce oil and gas as between owners of a common reservoir. Certain state regulatory authorities
also regulate the amount of oil and gas produced by assigning allowable rates of production to each well or proration unit. Pertinent state and federal statutes and regulations also extend to the prevention and clean-up of pollution. These laws and
regulations are subject to change and no predictions can be made as to what changes may be made or the effect of such changes on the Partnership’s operations. 

  
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 Under the laws and administrative regulations of the State of Oklahoma regarding forced pooling, owners of
oil and gas leases or unleased mineral interests may be required to elect to participate in the drilling of a well with other fractional undivided interest owners within an established spacing unit or to sell or farm out their interest therein. The
terms of any such sale or farm-out are generally those determined by the Oklahoma Corporation Commission to be equal to the most favorable terms then available in the area in arm’s length transactions although there can be no assurance that
this will be the case. In addition, if properties become the subject of a forced pooling order, drilling operations may have to be undertaken at a time or with other parties which the General Partner feels may not be in the best interest of the
Partnership. In such event, the Partnership may have to farm out or assign its interest in such properties. In addition, if a property which might otherwise be acquired by the Partnership becomes subject to such an order, it may become unavailable
to the Partnership. Finally, as a result of forced pooling proceedings involving a Partnership Property, the Partnership may acquire a larger than anticipated interest in such property, thereby increasing its share of the costs of operations to be
conducted. Other states in which the Partnership may engage in oil and gas exploration, drilling and development operations (see “Areas of Interest”) may have similar laws and administrative regulations. 

Natural Gas Price Regulation 

Partnership Revenues are likely to be dependent on the sale and transportation of natural gas that may be subject to regulation by the Federal Energy
Regulatory Commission (“FERC”). Historically the sale of natural gas has been regulated by the FERC under the Natural Gas Act of 1938 (“NGA”) and/or the Natural Gas Policy Act of 1978 (“NGPA”). The NGA conferred
jurisdiction on the FERC’s predecessor, the Federal Power Commission, to regulate the interstate transportation and sale of natural gas. The Act also established a certification system and required the FERC to ensure that all rates were
“just and reasonable” and that natural gas companies did not grant “undue preference[s].” Under this system, the FERC regulated both the wellhead price and the price charged by pipelines to end-users and local distribution
companies. 
 The NGPA began the gradual deregulation of prices at the wellhead. Under the NGPA, the FERC continued to regulate the maximum
selling prices of certain categories of gas sold in “first sales” in interstate and intrastate commerce. Effective January 1, 1993, however, the Natural Gas Wellhead Decontrol Act (the “Decontrol Act”) deregulated natural
gas prices for all “first sales” of natural gas. Because “first sales” include typical wellhead sales by producers, all natural gas produced from the Partnership’s natural gas properties will be sold at market prices,
subject to the terms of any private contracts which may be in effect. The FERC’s jurisdiction over natural gas transportation is not affected by the Decontrol Act. 
 Commencing in 1985, the FERC, through Order Nos. 436, 500, 636 and 637, promulgated changes that significantly affect the transportation and marketing of gas. These changes have been intended to foster
competition in the gas industry by, among other things, inducing or mandating that interstate pipeline companies provide nondiscriminatory transportation services to producers, distributors, buyers and sellers of gas and other shippers (so-called
“open access” requirements). The FERC has also sought to expedite the certification process for new services, facilities, and operations of those pipeline companies providing “open access” services. 

In 1992, the FERC issued Order 636 which, among other things, required each interstate pipeline company to “unbundle” its traditional wholesale
services and create and make available on an open and nondiscriminatory basis numerous constituent services (such as gathering services, storage services, firm and interruptible transportation services, and stand-by sales services) and to adopt a
new rate-making methodology to determine appropriate rates for those services. Each pipeline company was required to develop the specific terms of service in individual proceedings. The availability of non-discriminatory transportation services and
the ability of pipeline customers to modify or terminate their existing purchase obligations under these regulations have greatly enhanced the ability of producers to market their gas directly to end users and local distribution companies.

 As a result of these changes, sellers and buyers of natural gas have gained direct access to the particular pipeline services they need and
are better able to conduct business with a larger number of counter parties. The General Partner believes these changes generally have improved the access to markets for natural gas while, at the same time, substantially increasing competition in
the natural gas marketplace. The General Partner cannot predict what new or different regulations the FERC and other regulatory agencies may adopt or what effect subsequent regulations may have on Partnership Revenue. 

  
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 Oil Pipeline Regulation 
 With respect to oil pipeline rates subject to the FERC’s jurisdiction under the Interstate Commerce Act, in October 1993 the FERC issued Order 561 to implement the requirements of Title XVIII of the
Energy Policy Act of 1992. Order 561 established an indexing system, effective January 1, 1995, under which many oil pipelines are able to readily change their rates annually to track changes in the Producer Price Index for Finished Goods
(PPI-FG). This index established annual ceiling levels for rates effective July 1 of each year. Order 561 also permits cost-of-service proceedings to establish just and reasonable rates. The Order does not alter the right of a pipeline to seek
FERC authorization to charge market rates. However, until the FERC makes the finding that the pipeline does not exercise significant market power, the pipeline’s rates cannot exceed the applicable index ceiling level or a level justified by the
pipeline’s cost of service. 
 The FERC no longer regulates transportation rates for interstate oil gathering pipeline systems. However,
intrastate oil gathering pipelines are regulated in some states in which the Partnership may conduct oil and gas activities. 
 In addition, and
depending on other tariff provisions, the FERC has allowed some interstate tariffs for oil pipelines, particularly for new or expanded service, to contain allocation provisions which significantly limit the amount of space available for new shippers
during periods of prorationing. Similar allocation provisions may also exist in some intrastate oil pipeline tariffs. 
 State Regulation
of Oil and Gas Production 
 Most states in which the Partnership may conduct oil and gas activities regulate the production and sale of
oil and natural gas. Those states generally impose requirements or restrictions for obtaining drilling permits, the method of developing new fields, the spacing and operation of wells and the prevention of waste of oil and gas resources. In
addition, most states regulate the rate of production and may establish maximum daily production allowable from both oil and gas wells on a market demand or conservation basis. Until recently there has been no limit on allowable daily production on
the basis of market demand, although at some locations production continues to be regulated for conservation or market purposes. In 1992 Oklahoma and Texas imposed additional limitations on gas production to more closely track market demand. The
General Partner cannot predict whether any state regulatory agency may issue additional allowable reductions which may adversely affect the Partnership’s ability to produce its gas reserves. 

Legislative and Regulatory Production and Pricing Proposals 
 A number of legislative and regulatory proposals continually are advanced which, if put into effect, could have an impact on the petroleum industry. The various proposals involve, among other things, an
oil import fee, restructuring how oil pipeline rates are determined and implemented reducing production allowables, providing purchasers with “market-out” options in existing and future gas purchase contracts, eliminating or limiting the
operation of take-or-pay clauses, eliminating or limiting the operation of “indefinite price escalator clauses” (e.g., pricing provisions which allow prices to escalate by means of reference to prices being paid by other purchasers of
natural gas or prices for competing fuels), and state regulation of gathering systems. Proposals concerning these and other matters have been and will be made by members of the President’s office, Congress, regulatory agencies and special
interest groups. The General Partner cannot predict what legislation or regulatory changes, if any, may result from such proposals or any effect therefrom on the Partnership. 
 The effect of these regulations could be to decrease allowable production on Partnership Properties and thereby to decrease Partnership Revenues. However, by decreasing the amount of natural gas available
in the market, such regulations could also have the effect of increasing prices of natural gas, although there can be no assurance that any such increase will occur. There can also be no assurance that the proposed regulations described above will
be adopted or that they will be adopted on the terms set forth above. Additionally, such proposals, if adopted, are likely to be challenged in the courts and there can be no assurance as to the timing or the outcome of any such challenge.


  
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 Production and Environmental Regulation 

Certain states in which the Partnership may drill and own productive properties control production from wells through regulations establishing the spacing
of wells, limiting the number of days in a given month during which a well can produce and otherwise limiting the rate of allowable production. 

In addition, the federal government and various state governments have adopted laws and regulations regarding protection of the environment. These laws
and regulations may require the acquisition of a permit before or after drilling commences, impose requirements that increase the cost of operations, prohibit drilling activities on certain lands lying within wilderness areas or other
environmentally sensitive areas and impose substantial liabilities for pollution resulting from drilling operations, particularly operations in offshore waters or on submerged lands. 
 A past, present, or future release or threatened release of a hazardous substance into the air, water, or ground by the Partnership or as a result of disposal practices may subject the Partnership to
liability under the Comprehensive Environmental Response, Compensation and Liability Act, as amended (“CERCLA”), the Resource Conservation Recovery Act (“RCRA”), the Clean Water Act, the Clean Air Act, and/or similar state laws,
and any regulations promulgated pursuant thereto. Under CERCLA and similar laws, the Partnership may be fully liable for the cleanup costs of a release of hazardous substances even though it contributed to only part of the release. While liability
under CERCLA and similar laws may be limited under certain circumstances, typically the limits are so high that the maximum liability would likely have a significant adverse effect on the Partnership. In certain circumstances, the Partnership may
have liability for releases of hazardous substances by previous owners of Partnership Properties. Additionally, the discharge or substantial threat of a discharge of oil by the Partnership into United States waters or onto an adjoining shoreline may
subject the Partnership to liability under the Oil Pollution Act of 1990 and similar state laws. While liability under the Oil Pollution Act of 1990 is limited under certain circumstances, the maximum liability under those limits would still likely
have a significant adverse effect on the Partnership. The Partnership’s operations generally will be covered by the insurance carried by the General Partner or UNIT, if any. However, there can be no assurance that such insurance coverage will
always be in force or that, if in force, it will adequately cover any losses or liability the Partnership may incur. 
 Violation of
environmental legislation and regulations may result in the imposition of fines or civil or criminal penalties and, in certain circumstances, the entry of an order for the removal, remediation and abatement of the conditions, or suspension of the
activities, giving rise to the violation. The General Partner believes that the Partnership will comply with all orders and regulations applicable to its operations. However, in view of the many uncertainties with respect to the current controls,
including their duration and possible modification, the General Partner cannot predict the overall effect of such controls on such operations. Similarly, the General Partner cannot predict what future environmental laws may be enacted or regulations
may be promulgated and what, if any, impact they would have on operations or Partnership Revenue. 
 SUMMARY OF THE LIMITED
PARTNERSHIP AGREEMENT 
 The business and affairs of the Partnership and the respective rights and obligations of the Partners will be
governed by the Agreement. The following is a summary of certain pertinent provisions of the Agreement which have not been as fully discussed elsewhere in this Memorandum but does not purport to be a complete description of all relevant terms and
provisions of the Agreement and is qualified in its entirety by express reference to the Agreement. Each prospective subscriber should carefully review the entire Agreement. 
 Partnership Distributions 
 The General Partner will make quarterly determinations of
the Partnership’s cash position. If it determines that excess cash is available for distribution, it will be distributed to the Partners in the same proportions that Partnership Revenue has been allocated to them after giving effect to previous
distributions and to portions of such revenues theretofore used or expected to be thereafter used to pay costs incurred in conducting Partnership operations or to repay Partnership borrowings. It is expected that no cash distributions will be made
earlier than the first quarter of 2011. Distributions of cash determined by the General Partner to be available therefore will be made to the Limited Partners quarterly and to the General Partner at any time. All Partnership funds distributed to


  
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the Limited Partners shall be distributed to the persons who were record holders of Units on the day on which the distribution is made. Thus, regardless of when an assignment of Units is made,
any distribution with respect to the Units which are assigned will be made entirely to the assignee without regard to the period of time prior to the date of such assignment that the assignee holds the Units. 

The Partnership will terminate automatically on December 31, 2041 unless prior thereto the General Partner or Limited Partners holding a majority of
the outstanding Units elect to terminate the Partnership as of an earlier date. On termination of the Partnership, the debts, liabilities and obligations of the Partnership will be paid and the Partnership’s oil and gas properties and any
tangible equipment, materials or other personal property may be sold for cash. The cash received will be used to make certain adjusting payments to the Partners (see “SUMMARY OF THE LIMITED PARTNERSHIP AGREEMENT — Termination”). Any
remaining cash and properties will then be distributed to the Partners in proportion to and to the extent of any remaining balances in the Partners’ capital accounts and then in undivided percentage interests to the Partners in the same
proportions that Partnership Revenues are being shared at the time of such termination (see “SUMMARY OF THE LIMITED PARTNERSHIP AGREEMENT — Termination”). 
 Deposit and Use of Funds 
 Until required in the conduct of the Partnership’s
business, Partnership funds, including, but not limited to, the Capital Contributions, Partnership Revenue and proceeds of borrowings by the Partnership, will be deposited, with or without interest, in one or more bank accounts of the Partnership in
a bank or banks to be selected by the General Partner or invested in short-term United States government securities, money market funds, bank certificates of deposit or commercial paper rated as “A1” or “P1” as the General
Partner, in its sole discretion, deems advisable. Any interest or other income generated by such deposits or investments will be for the Partnership’s account. Except for Capital Contributions, Partnership funds from any of the various sources
mentioned above may be commingled with funds of the General Partner and may be used, expended and distributed as authorized by the terms and provisions of the Agreement. The General Partner will be entitled to prompt reimbursement of expenses it
incurs on behalf of the Partnership. 
 Power and Authority 
 In managing the business and affairs of the Partnership, the General Partner is authorized to take such action as it considers appropriate and in the best interests of the Partnership (see
Section 10.1 of the Agreement). The General Partner is authorized to engage legal counsel and otherwise to act with respect to Service audits, assessments and administrative and judicial proceedings as it deems in the best interests of the
Partnership and pursuant to the provisions of the Code. 
 The General Partner is granted a broad power of attorney authorizing it to execute
certain documents required in connection with the organization, qualification, continuance, modification and termination of the Partnership on behalf of the Limited Partners (see Sections 1.5 and 1.6 of the Agreement). Certain actions, such as an
assignment for the benefit of its creditors or a sale of substantially all of the Partnership Properties, except in connection with the termination, roll-up or consolidation of the Partnership, cannot be taken by the General Partner without the
consent of a majority in interest of the Limited Partners and the receipt of an opinion of Counsel as described under “Assignments by the General Partner” below (see Sections 10.15 and 12.1 of the Agreement). 

The Agreement provides that the General Partner will either conduct the Partnership’s drilling and production operations and operate each
Partnership Well or arrange for a third party operator to conduct such operations. The General Partner will, on behalf of the Partnership, enter into an appropriate operating agreement with the other owners of properties to be developed by the
Partnership authorizing either the General Partner or a third party operator to conduct such operations. The Partnership Agreement further provides that the Partnership will take such action in connection with operations pursuant to such operating
agreements as the General Partner, in its sole discretion, deems appropriate and in the best interests of the Partnership, and the decision of the General Partner with respect thereto will be binding on the Partnership. 

  
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 Rollup or Consolidation of the Partnership 

Two years or more after the Partnership has completed substantially all of its property acquisition, drilling and development operations, the General
Partner may, without the vote, consent or approval of the Limited Partners, cause all or substantially all of the oil and gas properties and other assets of the Partnership to be sold, assigned or transferred to, or the Partnership merged or
consolidated with, another partnership or a corporation, trust or other entity for the purpose of combining the assets of two or more of the oil and gas partnerships formed for investment or participation by employees, directors and/or consultants
of UNIT or any of its subsidiaries; provided, however, that the valuation of the oil and gas properties and other assets of all such participating partnerships for purposes of such transfer or combination shall be made on a consistent basis and in a
manner which the General Partner and UNIT believe is fair and equitable to the Limited Partners. As a consequence of any such transfer or combination, the Partnership will be dissolved and terminated and the Limited Partners shall receive
partnership interests, stock or other equity interests in the transferee or resulting entity. See “RISK FACTORS — Investment Risks - Roll-Up or Consolidation of the Partnership.” 

Limited Liability 
 Under the Act,
a limited partner is not generally liable for partnership obligations unless he or she takes part in the control of the business. The Agreement provides that the Limited Partners cannot bind or commit the Partnership or take part in the control of
its business or management of its affairs, and that the Limited Partners will not be personally liable for any debts or losses of the Partnership. However, the amounts contributed to the Partnership by the Limited Partners and the Limited
Partners’ interests in Partnership assets, including amounts of undistributed Partnership Revenue allocable to the Limited Partners, will be subject to the claims of creditors of the Partnership. A Limited Partner (or his or her estate) will be
obligated to contribute cash to the Partnership, even if the Limited Partner is unable to do so because of death, disability or any other reason, for: 
  

	 	(1)	any unpaid contribution which the Limited Partner agreed to make to the Partnership; and 


 

	 	(2)	any return, in whole or in part, of the Limited Partner’s contribution to the extent necessary to discharge Partnership liabilities to all creditors who extended
credit or whose claims arose before such return. 

 Liability of a Limited Partner is limited by the Act to one year for any
return of his or her contribution not in violation of the Partnership Agreement or such Act and six years on any return of his or her contribution in violation of the Partnership Agreement or such Act. A partner is deemed to have received a return
of his or her contribution to the extent that a distribution to him or her reduces his or her share of the fair value of the net assets of the Partnership below the value of his or her contribution which has not been distributed to him or her. How
this provision applies to a partnership whose primary assets are producing oil and gas properties or other depleting assets is not entirely clear. The Agreement provides that for the purposes of this provision, the value of a Limited Partner’s
contribution which has not been distributed to him or her at any point in time will be the Limited Partner’s Percentage of the stated capital of the Partnership allocated to the Limited Partners as reflected in its financial statements as of
such point in time. 
 Maintenance of limited liability of the Limited Partners in other jurisdictions in which the Partnership may operate may
require compliance with certain legal requirements of those jurisdictions. In such jurisdictions, the General Partner shall cause the Partnership to operate in such a manner as it, on the advice of responsible Counsel, deems appropriate to avoid
unlimited liability for the Limited Partners (see Sections 1.5, 12.1 and 12.2 of the Agreement). After the termination of the Partnership, any distribution of Partnership Properties to the Limited Partners would result in their having unlimited
liability with respect to such properties. 
 Although the Partnership will, with certain limited exceptions, serve as a co-general partner of
any drilling or income programs formed by UNIT or UPC in 2011 (see “PROPOSED ACTIVITIES”), the general liability of the Partnership will not flow through to the Limited Partners. 
 Records, Reports and Returns 
 The General Partner will maintain adequate books,
records, accounts and files for the Partnership and keep the Limited Partners informed by means of written interim reports rendered within 60 days after each quarter of the Partnership’s fiscal year. The reports will set forth the source and
disposition of Partnership Revenues during the quarter. 

  
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 Engineering reports on the Partnership Properties will be prepared by the General Partner for each year for
which the General Partner prepares such a report in connection with its own activities. Such report will include an estimate of the total oil and gas proven reserves of the Partnership, the dollar value thereof and the value of the Limited
Partners’ interest in such reserve value. The report shall also contain an estimate of the life of the Partnership Properties and the present worth of the reserves. Each Limited Partner will receive a summary statement of such report which will
reflect the value of the Limited Partners’ interest in such reserves. 
 The General Partner will timely file the Partnership’s income
tax returns and by March 15 of each year or as soon thereafter as practicable, furnish each person who was a Limited Partner during the prior year all available information necessary for inclusion in his or her federal income tax return. (See
Section 8.1 of the Agreement). 
 Transferability of Interests 
 Restrictions. A Limited Partner may not transfer or assign Units except for certain transfers: 
  

	 	•	 	 to the General Partner; 


  

	 	•	 	 to or for the benefit of himself or herself, his or her spouse, or other members of the transferor Limited Partner’s immediate family sharing the
same residence; 


  

	 	•	 	 to any corporation or other entity whose beneficial owners are all Limited Partners or permitted assignees; 



 

	 	•	 	 by the General Partner to any person who at the time of such transfer is an employee of the General Partner, UNIT or its subsidiaries; and



  

	 	•	 	 by reason of death or operation of law. 


 Further, no sale or exchange of any Units may be made if the sale of such interest would, in the opinion of counsel for the Partnership, result in a termination of the Partnership for purposes of
Section 708 of the Code, violate any applicable securities laws or cause the Partnership to be treated as an association taxable as a corporation or publicly traded partnership for federal income tax purposes; provided, however, that this
condition may be waived by the General Partner, in its sole discretion. Moreover, in no event shall all or any portion of a Limited Partner’s Units be assigned to a minor or an incompetent, except by will, intestate succession, in trust, or
pursuant to the Uniform Transfers to Minors Act. 
 As the offer and sale of the Units are not being registered under the Securities Act of
1933, as amended, they may be sold, transferred, assigned or otherwise disposed of by a Limited Partner only if, in the opinion of counsel for the Partnership, such transfer or assignment would not violate, or cause the offering of the Units to be
violative of, such act or applicable state securities laws, including investor suitability standards thereunder. Because of the structure and anticipated operation of the Partnership, Rule 144 under the Securities Act of 1933 will not be available
to Limited Partners in connection with any such sales. 
 Assignees. An assignee of a Limited Partner does not automatically
become a Substituted Limited Partner, but has the right to receive the same share of Partnership Revenue and distributions thereof to which the assignor Limited Partner would have been entitled. A Limited Partner who assigns his or her Partnership
interest ceases to be a Limited Partner, except that until a Substituted Limited Partner is admitted in his or her place, the assignor retains the statutory rights of an assignor of a Limited Partner’s interest under the partnership laws of the
State of Oklahoma. The assignee of a Partnership interest who does not become a Substituted Limited Partner and desires to make a further assignment of such interest is subject to all of the restrictions on transferability of Partnership interests
described herein and in the Partnership Agreement. 
 In the event of the death, incapacity or bankruptcy of a Limited Partner, his or her legal
representatives will have all the rights of a Limited Partner only for the purpose of settling or liquidating his or her estate and such power as the decedent, incompetent or bankrupt Limited Partner possessed to assign all or any part of his or her
interest in the Partnership and to join with such assignee in satisfying conditions precedent to such assignee’s becoming a Substituted Limited Partner. 

  
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 A purported sale, assignment or transfer of a Limited Partner’s interest will be recognized by the
Partnership when it has received written notice of such sale or assignment in form satisfactory to the General Partner, signed by both parties, containing the purchaser’s or assignee’s acceptance of the terms of the Agreement and a
representation by the parties that the sale or assignment was lawful. Such sale or assignment will be recognized as of the date of such notice, except that if such date is more than 30 days prior to the time of filing, such sale or assignment will
be recognized as of the time the notice was filed with the Partnership. Distributions of Partnership Revenue will be made only to those persons who were record owners of Units on the day any such distribution is made. 

Substituted Limited Partners. No Limited Partner has the right to substitute an assignee as a Limited Partner in his or her place. The
General Partner, however, has the right in its sole discretion to permit such assignee to become a Substituted Limited Partner and any such permission by the General Partner is binding and conclusive without the consent or approval of any Limited
Partner. Any Substituted Limited Partner must, as a condition to receiving any interest of the Limited Partner, agree in writing to be bound by the terms and conditions of the Partnership Agreement, pay or agree to pay the costs and expenses
incurred by the Partnership in taking the actions necessary in connection with his or her substitution as a Limited Partner and satisfy the other conditions specified in Article XIII of the Partnership Agreement. 

Assignments by the General Partner. The General Partner may not sell, assign, transfer or otherwise dispose of its interest in the
Partnership except with the prior consent of a majority in interest of the Limited Partners, provided that no such consent is required if the sale, assignment or transfer is pursuant to a bona fide merger, other corporate reorganization or complete
liquidation, sale of substantially all of the General Partner’s assets (provided the purchasers agree to assume the duties and obligations of the General Partner) or any sale or transfer to UNIT or any affiliate of UNIT. Any consent of the
Limited Partners will not be effective without an opinion of counsel to the Partnership or an order or judgment of a court of competent jurisdiction to the effect that the exercise of such right will not be deemed to evidence that the Limited
Partners are taking part in the management of the Partnership’s business and affairs and will not result in a loss of any Limited Partner’s limited liability or cause the Partnership to be classified as an association taxable as a
corporation or publicly traded partnership for federal income tax purposes (see Section 12.1 of the Agreement). Any transferee of the General Partner’s interest may become a substitute General Partner by assuming and agreeing to perform
all of the duties and obligations of a General Partner under the Agreement. In such event, the transferring General Partner, on making a proper accounting to the substitute General Partner, will be relieved of any further duties or obligations with
respect to any future Partnership operations. 
 Amendments 
 The Agreement may be amended on the approval by a majority in interest of the Limited Partners, except that amendments changing the Partners’ participation in costs and revenues, increasing or
decreasing the General Partner’s compensation or otherwise materially and adversely affecting the interests of either the Limited Partners or the General Partner must be approved by all Limited Partners if their interests would be adversely
affected thereby or by the General Partner if its interest would be adversely affected thereby. The Limited Partners have no right to propose amendments to the Agreement. 
 Voting Rights 
 Under the Agreement, the Limited Partners will have very limited
rights to vote on any Partnership matters. Except for certain special amendments referred to under “Amendments” above, matters submitted to the Limited Partners for determination will be determined by the affirmative vote of Limited
Partners holding a majority of the outstanding Units. Units held by the General Partner may be voted by it. 
 Generally, Limited Partners
owning more than 50% of the outstanding Units of the Partnership may, without the necessity of concurrence by the General Partner, vote to: 
  

	 	•	 	 Approve the execution or delivery of any assignment for the benefit of the Partnership’s creditors; 



  
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	 	•	 	 Approve the sale or disposal of all or substantially all of the Partnership’s assets, except pursuant to (i) a rollup or consolidation of the
Partnership (see “Rollup or Consolidation of the Partnership” above) or (ii) termination (see “Termination” below); 


  

	 	•	 	 Approve the General Partner’s sale, assignment, transfer or disposal of its interest in the Partnership, unless such sale, assignment or transfer
is pursuant to (i) a merger or other corporate reorganization, or liquidation or sale of substantially all of its assets, and the purchaser agrees to assume the duties and obligations of the General Partner, or (ii) any sale to UNIT or its
affiliates; 


  

	 	•	 	 Terminate and dissolve the Partnership; or 


  

	 	•	 	 Approve any amendments to the Agreement which may be proposed by the General Partner; 



provided, however, any approvals, consents or elections of the Limited Partners will not become effective unless prior to the exercise thereof the
General Partner is furnished with an opinion of counsel for the Partnership, or an order or judgment of any court of competent jurisdiction, that the exercise of such rights: 

 

	 	•	 	 Will not be deemed to evidence that the Limited Partners are taking part in the control or management of the Partnership’s business affairs;



  

	 	•	 	 Will not result in the loss of any Limited Partner’s limited liability under the Act; and 



 

	 	•	 	 Will not result in the Partnership being classified as an association taxable as a corporation for federal income tax purposes.



 Exculpation and Indemnification of the General Partner 

Pursuant to the Agreement, neither the General Partner or any affiliate thereof will have any liability to the Partnership or to any Partners therein for
any loss suffered by the Partnership or such Partner that arises out of any action or inaction of the General Partner or any affiliate thereof if the General Partner or affiliate thereof in good faith determined that such course of conduct was in
the best interest of the Partnership, the General Partner or affiliate was acting on behalf of or performing services for the Partnership, such liability or loss was not the result of gross negligence or willful misconduct by the General Partner or
affiliates thereof, and payments arising from such indemnification or agreement to hold harmless are receivable only out of the tangible net assets of the Partnership. 
 Termination 
 The Partnership will terminate automatically on December 31, 2041.
In addition, on the dissolution (other than pursuant to a merger, or other corporate reorganization or sale), bankruptcy, legal disability or withdrawal of the General Partner, the Partnership shall immediately be dissolved and terminated. The Act
provides, however, that the Limited Partners may elect to reform and reconstitute themselves as a limited partnership within 90 days after such dissolution under the provisions in the Partnership Agreement or under any other terms. The Partnership
may terminate sooner if a majority in interest of the Limited Partners or the General Partner elects to dissolve and terminate the Partnership as of an earlier date. Such right to accelerate termination of the Partnership by the Limited Partners
will not be available unless prior to any exercise thereof the Limited Partners proposing such termination obtain and furnish to the General Partner an opinion, order or judgment in the form referred to above under “Transferability of Interests
- Assignments by the General Partner.” The withdrawal, expulsion, dissolution, death, legal disability, bankruptcy or insolvency of any Limited Partner will not effect a dissolution or termination of the Partnership. In the event of an election
to terminate the Partnership prior to expiration of its stated terms, 90 days’ prior written notice must be given to all Partners specifying the termination date which must be the last day of a calendar month following such 90 day period unless
an earlier date is approved by Limited Partners holding a majority of the outstanding Units. 
 When the Partnership is terminated, there will
be an accounting with respect to its assets, liabilities and accounts. The Partnership’s physical property and its oil and gas properties may be sold for cash. Except in the case of an election by the General Partner to terminate the
Partnership before the tenth anniversary of the Effective Date, Partnership Properties may be sold to the General Partner or any of its affiliates for their fair market value as determined in good faith by the General Partner. 

  
 69 









 On termination, all of the Partnership’s debts, liabilities and obligations, including expenses
incurred in connection with the termination and the sale or distribution of Partnership assets, will be paid. All Partnership borrowings will be paid in full. When the specified payments have all been made, the remaining cash and properties of the
Partnership, if any, will be distributed to the Partners as set forth under “Partnership Distributions” above (see Section 16.4 of the Agreement). Such distribution will result in the Limited Partners’ having unlimited liability
with respect to any Partnership Properties distributed to them. 
 Insurance 

The General Partner will use its best efforts to obtain such insurance as it deems prudent to serve as protection against liability for loss and damage.
Such insurance may include, but is not limited to, public liability, automotive liability, workers’ compensation and employer’s liability insurance and blowout and control of well insurance. 

COUNSEL 

Conner & Winters, LLP, 4000 One Williams Center, Tulsa, Oklahoma 74172-0148, has acted as special counsel to the General Partner in connection
with certain aspects of this offering. Conner & Winters has assisted in the preparation of the Agreement and this Memorandum. In connection with the preparation of this Memorandum, Conner & Winters has relied entirely on
information submitted to it by the General Partner. Certain of this information has been verified by Conner & Winters in the course of its representation, but no systematic effort has been made to verify all of the material information
contained herein, and much of such information is not subject to independent verification. In addition, Conner & Winters has made no independent investigation of the financial information concerning the General Partner. Further, while
passing on certain legal matters, Conner & Winters has not passed on the investment merits nor is it qualified to do so. Because substantial portions of the information contained in this Memorandum have not been independently verified, each
investor must make whatever independent inquiries the investor or his or her advisors deem necessary or desirable to verify or confirm the statements made herein. 
 GLOSSARY 
 As used herein and in the Agreement, the following terms and phrases will have
the meanings indicated. 
 (a) “Additional
Assessments” are amounts required to be contributed by the Limited Partners to the Partnership on a call therefore by the General Partner in the manner described under “ADDITIONAL FINANCING
— Additional Assessments.” 
 (b) An “affiliate” of another person is
(1) any person directly or indirectly owning, controlling or holding with power to vote 10% or more of the outstanding voting securities of such other person; (2) any person 10% or more of whose outstanding voting securities are directly
or indirectly owned, controlled, or held with power to vote, by such other person; (3) any person directly or indirectly controlling, controlled by, or under common control with such other person; (4) any officer, director, trustee or
partner of such other person; and (5) if such other person is an officer, director, trustee or partner, any company for which such person acts in any such capacity. 
 (c) The “Aggregate Subscription” is the sum of the Capital Subscriptions of all Limited Partners. 

(d) “Agreement” and “Partnership
Agreement” refers to the Agreement of Limited Partnership attached as Exhibit A to this Private Offering Memorandum. 
 (e) The “Capital Contribution” of a Limited Partner is the amount of the Capital Subscription actually paid in by him or her, or by any predecessor in
interest, to the capital of the Partnership including any payments made by deductions from salary. The “Capital Contribution” of the General Partner includes the amounts contributed to the Partnership or paid by the General Partner or by
any Limited Partner whose Units are purchased by the General Partner pursuant to Section 4.2 of the Agreement because of a default by such Limited Partner in the payment of an Installment or pursuant to Article XV of the Agreement, including
payments made by deductions from the salary of such Limited Partner. 

  
 70 









 (f) The “Capital Subscription” of a Limited Partner or his or her
assignee (including the General Partner where Units are transferred pursuant to Section 4.2 of the Agreement) is the amount specified in the Subscription Agreement executed by such Limited Partner for payment by him or her to the capital of the
Partnership in accordance with the provisions of the Agreement, reduced by the amounts thereof from which the Limited Partners have been released by the General Partner of their obligation to pay. 

(g) A “Development Well” means a well intended to be drilled within the proved areas of a known oil or gas
reservoir to the depth of a stratigraphic horizon known to be productive. 
 (h) “Director” refers to the
duly elected directors of UNIT as well as all honorary directors and consultants to the Board of Directors of UNIT. 
 (i)
“Drilling Costs” are those costs incurred in drilling, testing, completing and equipping a well to the point that it proves to be dry and is abandoned or is ready to commence commercial production of oil or gas
therefrom. 
 (j) “Effective Date” refers to the date on which the certificate evidencing formation of the
Partnership is filed with the Secretary of State of the State of Oklahoma as required by the Act (54 Okla. Stat. 2001, Section 309). 
 (k)
An “Exploratory Well” means a well drilled to find production in an unproven area, to find a new reservoir in a field previously found to be productive or to extend greatly the limits of a known reservoir.

 (l) A “farm-out” is an agreement whereby the owner of an oil and gas property agrees to assign such
property, usually retaining some interest therein such as an overriding royalty, a production payment, a net profits interest or a carried working interest, subject in most cases, however, to the drilling of one or more wells or other performance by
the prospective assignee as a condition of the assignment. 
 (m) The “General Partner’s Minimum Capital
Contribution” is that amount equal to the total of (i) all Partnership costs and expenses charged to its account from the time of the formation of the Partnership through December 31, 2011, plus (ii) the General
Partner’s estimate of the total Leasehold Acquisition Costs and Drilling Costs expected to be incurred by the Partnership subsequent to December 31, 2011, if any, minus (iii) the amount, if any, of the unexpended Aggregate
Subscription at December 31, 2011. 
 (n) The “General Partner’s Percentage” is that percentage
determined by dividing the amount of the General Partner’s Minimum Capital Contribution by the total of (i) the General Partner’s Minimum Capital Contribution plus (ii) the Aggregate Subscription. 

(o) “Installments” refer to the periodic payments of the Capital Subscription, which are payable either (i) in
four equal installments due on March 15, June 15, September 15, 2011 and December 15, 2011, respectively, or (ii) if an employee so elects, through equal deductions from 2011 salary commencing immediately after
formation of the Partnership. 
 (p) “Leasehold Acquisition Costs” with respect to properties, if any,
acquired by the Partnership from non-affiliated parties mean the actual costs to the Partnership of and in acquiring the properties, and, with respect to properties acquired by the Partnership from the General Partner, UNIT or its affiliates are,
without duplication, the sum of: 
  

	 	(1)	the prices paid by the General Partner, UNIT or its affiliates in acquiring an oil and gas property, including purchase option fees and charges, bonuses and penalties,
if any; 

  

	 	(2)	title insurance or examination costs, broker’s commissions, filing fees, recording costs, transfer taxes, if any, and like charges incurred in connection with the
acquisition of such property; 

  

	 	(3)	a pro rata portion of the actual, necessary and reasonable expenses of the General Partner, UNIT or its affiliates for seismic and geophysical services;


  

	 	(4)	rentals, shut-in royalties and ad valorem taxes paid by the General Partner, UNIT or its affiliates with respect to such property to the date of its transfer to the
Partnership; 

  

	 	(5)	interest and points actually incurred on funds used by the General Partner, UNIT or its affiliates to acquire or maintain such property; and 


  
 71 










	 	(6)	such portion of the General Partner’s, UNIT or its affiliates’ reasonable, necessary and actual expenses for geological, engineering, drafting, accounting,
legal and other like services allocated to the acquisition, operations and maintenance of the property in accordance with generally accepted industry practices, except for expenses in connection with the past drilling of wells which are not
producers of sufficient quantities of oil or gas to make commercially reasonable their continued operations, and provided that the costs and expenses enumerated in (4), (5) and (6) above with respect to any particular property shall have
been incurred not more than thirty-six (36) months prior to the acquisition of such property by the Partnership. 

 In the
event a fractional undivided interest in a property is sold or transferred by the General Partner, UNIT or any affiliate to an unaffiliated third party for an amount in excess of that portion of the original cost of the property attributable to the
transferred interest, the amount of such excess shall not reduce or be offset against the amount of the Leasehold Acquisition Costs attributable to any interest in the same property which is transferred to the Partnership. 

(q) “Limited Partners” are those persons who acquire Units in the Partnership on its formation and those
transferees of Units who are accepted as Substituted Limited Partners. The General Partner may also be a Limited Partner if it subscribes for Units or if it subsequently acquires Units by (i) the exercise by a Limited Partner of his or her
right of presentment; (ii) a purchase by the General Partner of the Units of a Limited Partner who defaults in the payment of an Installment; or (iii) any other assignment or transfer. 

(r) The “Limited Partners’ Percentage” is that percentage determined by dividing the amount of the Aggregate
Subscription by the total of (i) the General Partner’s Minimum Capital Contribution plus (ii) the Aggregate Subscription. 
 (s)
“Normal Retirement” means retirement under the terms of a pension or similar retirement plan adopted by the General Partner, UNIT or any subsidiary with whom a Limited Partner is employed as in effect at the
time of retirement. 
 (t) “Oil and gas properties” are oil and gas leasehold working interests, fee
interests, mineral interests, royalty interests, overriding royalty interests, production payments, options or rights to lease or acquire such interests, geophysical exploration permits and any tangible or intangible properties or other rights
incident thereto, whether real, personal or mixed. 
 (u) “Operating Expenses” are expenditures made and
costs incurred in producing and marketing oil or gas from completed wells, including, in addition to labor, fuel, repairs, hauling, material, supplies, utility charges and other costs incident to or necessary for the maintenance or operation of such
wells or the marketing of production therefrom, ad valorem, severance and other such taxes (other than windfall profit taxes), insurance and casualty loss expense and compensation to well operators or others for services rendered in conducting such
operations. 
 (v) The General Partner and the Limited Partners are sometimes collectively referred to as the
“Partners.” 
 (w) “Partnership Agreement” and
“Agreement” refer to the Agreement of Limited Partnership attached as Exhibit A to this Private Offering Memorandum. 
 (x) The “Partnership Properties” are oil and gas properties or interests therein acquired by the Partnership or properties acquired by any partnership or joint
venture in which the Partnership is a partner or joint venturer, whether acquired by purchase, option exercise or otherwise. 
 (y)
“Partnership Revenue” refers to the Partnership’s gross revenues from all sources, including interest income, proceeds from sales of production, the Partnership’s share of revenues from partnerships or
joint ventures of which it is a member, sales or other dispositions of Partnership Properties or other Partnership assets, provided that contributions to Partnership capital by the Partners and the proceeds of any Partnership borrowings are
specifically excluded and dry-hole and bottom-hole contributions shall be treated as reductions of the costs giving rise to the right to receive such contributions. 
 (z) “Partnership Wells” are any and all of the oil and gas wells in which the Partnership has an interest, either directly or indirectly through any other partnership
or joint venture. 

  
 72 









 (aa) “Productive properties” are oil and gas properties that have been
tested by drilling and determined to be capable of producing oil or gas in commercial quantities. 
 (bb) A “spacing
unit” is a drilling and spacing, production or similar unit established by any regulatory body with jurisdiction, or in the absence of such a regulatory body or action thereby, the acreage attributable to wells drilled under the
normal spacing pattern in such area or if no such spacing unit is designated, in keeping with generally accepted industry practices, or the largest of such units in the event of multiple objective formations. 

(cc) “Special Production and Marketing Costs” are costs and expenses that are not normally and customarily incurred
in connection with drilling, producing and marketing operations, including without limitation, costs incurred in constructing compressor plants and pumping stations, gasoline plants, gas or oil gathering systems, natural gas processing plants,
pipeline systems and salt water disposal systems and costs incurred in installing pressure maintenance and secondary or tertiary production projects. 
 (dd) “Subscription Agreement” refers to the form of Limited Partner Subscription Agreement and Suitability Statement attached as Attachment I to the Partnership
Agreement. 
 (ee) A “Substituted Limited Partner” is a transferee, donee, heir, legatee or other
recipient of all or any portion of a Limited Partner’s interest in the Partnership with respect to whom all conditions and consents required to become a Substituted Limited Partner under Article XIII of the Partnership Agreement have been
satisfied and given. 
 (ff) A “Unit” is a preformation unit of limited
partnership interest of a Limited Partner in the Partnership representing a Capital Subscription of One Thousand Dollars ($1,000). 

  
 73 









 FINANCIAL STATEMENTS 
 Unit Petroleum Company functions as the operating entity for all oil and natural gas exploration and production activities including operating any partnerships for UNIT. 

The consolidated balance sheet of Unit Petroleum Company at October 31, 2010 is unaudited and includes all adjustments which UNIT considers
necessary for a fair presentation of the financial position of Unit Petroleum Company at October 31, 2010. 
 Unit Petroleum
Company 
 Consolidated Balance Sheet 
 (In Thousands) 
  

					
	 	  	October 31, 2010	 
	 	  	(Unaudited)	 
	 Assets
	  			
	 Current Assets:
	  			
	 Cash and cash equivalents
	  	$	679	  
	 Trade accounts receivable
	  	 	40,949	  
	 Materials and supplies, at lower of cost or market
	  	 	7,068	  
	 Other
	  	 	20	  
		  	 	 	 
	 Total current assets
	  	 	48,716	  
		  	 	 	 
	 Property and Equipment:
	  			
	 Oil and natural gas properties, on the full cost method
	  	 	2,810,929	  
	 Other
	  	 	4,433	  
		  	 	 	 
		  	 	2,815,362	  
	 Less accumulated depreciation, depletion, amortization and impairment
	  	 	1,516,300	  
		  	 	 	 
	 Net property and equipment
	  	 	1,299,062	  
		  	 	 	 
	 Other Assets
	  	 	84	  
		  	 	 	 
	 Total Assets
	  	$	1,347,862	  
		  	 	 	 
		
	Liabilities and Shareholders’ Equity	  			
	 Current Liabilities:
	  			
	 Current portion of long-term liabilities
	  	$	1,621	  
	 Accounts payable
	  	 	23,126	  
	 Accounts payable to parent
	  	 	394,373	  
	 Contract advances
	  	 	2,842	  
	 Accrued liabilities
	  	 	10,416	  
		  	 	 	 
	 Total current liabilities
	  	 	432,378	  
		  	 	 	 
	 Other Long-Term Liabilities
	  	 	66,544	  
		  	 	 	 
	 Deferred Income Taxes
	  	 	296,496	  
		  	 	 	 
	 Shareholders’ Equity:
	  			
	 Common stock, $1.00 par value, 500 shares authorized and outstanding
	  	 	1	  
	 Capital in excess of par value
	  	 	31,543	  
	 Retained earnings
	  	 	520,900	  
		  	 	 	 
	 Total shareholders’ Equity
	  	 	552,444	  
		  	 	 	 
	 Total Liabilities and Shareholders’ Equity
	  	$	1,347,862	  
		  	 	 	 


  
 74 









 EXHIBIT A 
 UNIT 2011 EMPLOYEE OIL AND GAS LIMITED PARTNERSHIP 
 AGREEMENT OF LIMITED
PARTNERSHIP 

  
 A-1









 INDEX 

 

					
		
	 ARTICLE I Formation of Limited Partnership
	  	 	A-3	  
		
	 ARTICLE II Definitions
	  	 	A-4	  
		
	 ARTICLE III Purposes and Powers of the Partnership
	  	 	A-7	  
		
	 ARTICLE IV Partner Capital Contributions
	  	 	A-8	  
		
	 ARTICLE V Deposit and Use of Capital Contributions and Other Partnership Funds
	  	 	A-10	  
		
	 ARTICLE VI Sharing of Costs, Capital Accounts and Allocation of Charges and Income
	  	 	A-11	  
		
	 ARTICLE VII Fiscal Year, Accountings and Reports
	  	 	A-15	  
		
	 ARTICLE VIII Tax Returns and Elections
	  	 	A-15	  
		
	 ARTICLE IX Distributions
	  	 	A-16	  
		
	 ARTICLE X Rights, Duties and Obligations of the General Partner
	  	 	A-16	  
		
	 ARTICLE XI Compensation and Reimbursements
	  	 	A-20	  
		
	 ARTICLE XII Rights and Obligations of Limited Partners
	  	 	A-21	  
		
	 ARTICLE XIII Transferability of Limited Partner’s Interest
	  	 	A-21	  
		
	 ARTICLE XIV Assignments by the General Partner
	  	 	A-23	  
		
	 ARTICLE XV Limited Partners’ Right of Presentment
	  	 	A-24	  
		
	 ARTICLE XVI Termination and Dissolution of Partnership
	  	 	A-25	  
		
	 ARTICLE XVII Notices
	  	 	A-27	  
		
	 ARTICLE XVIII Amendments
	  	 	A-27	  
		
	 ARTICLE XIX General Provisions
	  	 	A-28	  
		
	 ATTACHMENT I Limited Partner Subscription Agreement and Suitability Statement
	  	 	I-1	  


  
 A-2









 UNIT 2011 EMPLOYEE OIL AND GAS LIMITED PARTNERSHIP 

AGREEMENT OF LIMITED PARTNERSHIP 
 THIS AGREEMENT OF LIMITED PARTNERSHIP (this “Agreement”) is made and entered into by and among Unit Petroleum Company, an Oklahoma corporation, hereinafter referred to as the
“General Partner” or “UPC” (which term shall include any successors or assigns of UPC), and each of those persons who have executed a counterpart of the Limited Partner Subscription Agreement and Suitability
Statement attached as Attachment I to this Agreement that have been accepted by the General Partner, said persons being hereinafter collectively referred to as the “Limited Partners.” 

WITNESSETH THAT: 
 ARTICLE I 
 Formation of Limited Partnership 

1.1 The parties to this Agreement hereby form a Limited Partnership (the “Partnership”) pursuant to the Revised Uniform
Limited Partnership Act of the State of Oklahoma (the “Act”). The terms and provisions hereof will be construed and interpreted in accordance with the terms and provisions of the Act and if any of the terms and provisions of this
Agreement should be deemed inconsistent with those terms and provisions of the Act which under the Act may not be altered by agreement of the parties, the Act will be controlling, but otherwise this Agreement will be controlling. 

1.2 The Partnership will be conducted under the name of “Unit 2011 Employee Oil and Gas Limited Partnership” in Oklahoma, and
under such name or variations of such name as the General Partner deems appropriate to comply with the laws of the other jurisdictions in which the Partnership does business. 
 1.3 The principal office of the Partnership will be 7130 South Lewis Avenue, Suite 1000, Tulsa, Oklahoma 74136, or at such other location as may from time to time be designated by the General Partner, and
the Partnership’s agent for service of process shall be Unit Corporation (“UNIT,” which term shall include all or any of its subsidiaries or affiliates unless the context otherwise requires) at the same address. 

1.4 The Partnership will be effective on the date on which the certificate evidencing formation of the Partnership is filed with the
Secretary of State of the State of Oklahoma. Its business and operations will not be commenced prior to such date. The Partnership will continue in existence until December 31, 2041, unless sooner terminated pursuant to any provisions of this
Agreement. 
 1.5 The parties hereto will execute such certificates and other documents, and the General Partner will file,
record and publish such certificates and documents, as may be necessary or appropriate to comply with the requirements for the formation and operation of a limited partnership under the Act and as the General Partner, upon advice of counsel, deems
necessary or appropriate to comply with requirements of applicable laws governing the formation and operations of a limited partnership (or a partnership in which special partners have a limited liability) in all other jurisdictions where the
Partnership desires to conduct business, including, but not limited to, filings under the Fictitious Name Act, Assumed Name Act or similar law in effect in the counties, parishes and other governmental jurisdictions in which the Partnership conducts
business. The General Partner shall not be required to deliver or mail a copy of the certificate of limited partnership or any amendments thereto filed pursuant to the Act to the Limited Partners. 

1.6 Each Limited Partner by his or her execution of a counterpart of the Subscription Agreement irrevocably constitutes and appoints the
General Partner such Limited Partner’s true and lawful attorney and agent, with full power and authority in such Limited Partner’s name, place and stead, to execute, sign, acknowledge, swear to, deliver, file and record in the appropriate
public offices (i) all certificates or other instruments (including, without limitation, counterparts of this Agreement) and 

  
 A-3









 
amendments thereto which the General Partner deems appropriate to qualify or continue the Partnership as a limited partnership (or a partnership in which special partners have limited liability)
in the jurisdictions in which the Partnership conducts business; (ii) all instruments and amendments thereto which the General Partner deems appropriate to reflect any change or modification of this Agreement, the admission of additional or
substitute Partners in accordance with the terms of this Agreement, the release or waiver of the Limited Partners from the obligation to pay in one or more of the installments of their Capital Subscriptions pursuant to Section 4.2 below and the
termination of the Partnership and the cancellation of the certificate of limited partnership; (iii) all conveyances and other instruments which the General Partner deems appropriate to evidence and reflect any sales or transfers, including
sales or transfers upon or in connection with the dissolution and termination of the Partnership; and (iv) all consents to transfers of Partnership interests, to the admission of substitute or additional Partners or to the withdrawal or
reduction of any Partner’s invested capital, to the extent that such actions are authorized by the terms of this Agreement. The Power of Attorney granted herein is irrevocable and is a power coupled with an interest and will survive the death,
disability, dissolution, bankruptcy, insolvency or incapacity of a Limited Partner. 
 ARTICLE II 

Definitions 
 2.1 Whenever used in this Agreement the following terms will have the meanings described below: 
 (a) The “Additional Assessments” of the Limited Partners are those amounts, if any, which they are required to pay into the capital of the Partnership pursuant to Section 5.3
of this Agreement. 
 (b) An “affiliate” of another person is (1) any person
directly or indirectly owning, controlling or holding with power to vote 10% or more of the outstanding voting securities of such other person; (2) any person 10% or more of whose outstanding voting securities are directly or indirectly owned,
controlled, or held with power to vote, by such other person; (3) any person directly or indirectly controlling, controlled by, or under common control with such other person; (4) any officer, director, trustee or partner of such other
person; and (5) if such other person is an officer, director, trustee or partner, any company for which such person acts in any such capacity. 
 (c) The “Aggregate Subscription” is the sum of the Capital Subscriptions of all Limited Partners. 

(d) The “Capital Contribution” of a Limited Partner is the amount of the Capital Subscription
actually paid in by him or her, or by any predecessor in interest, to the capital of the Partnership, including any payments made by deductions from salary. The “Capital Contribution” of the General Partner includes the amounts contributed
to the Partnership or paid by the General Partner or by any Limited Partner whose Units are purchased by the General Partner including purchases pursuant to Section 4.2 of this Agreement because of a default by such Limited Partner in the
payment of a subscription installment or pursuant to Article XV of this Agreement, including payments made by deductions from the salary of such Limited Partner. 

(e) The “Capital Subscription” of a Limited Partner or his or her assignee (including the General
Partner where Units are transferred pursuant to Section 4.2 of this Agreement) is the amount specified in the Subscription Agreement executed by such Limited Partner for payment by him or her to the capital of the Partnership in accordance with
the provisions of this Agreement, reduced by the amount thereof from which the Limited Partner has been released by the General Partner of his or her obligation to pay pursuant to Section 4.2 hereof. 

  
 A-4









 (f) “Drilling Costs” are those costs incurred in
drilling, testing, completing and equipping a Partnership Well to the point that it proves to be dry and is abandoned or is ready to commence commercial production of oil or gas therefrom. 

(g) “Effective Date” refers to the date on which the certificate evidencing formation of the
Partnership is filed with the Secretary of State of the State of Oklahoma as required by the Act. 
 (h) A
“farm-out” is an agreement whereby the owner of an oil and gas property agrees to assign such property, usually retaining some interest therein such as an overriding royalty, a production payment, a net profits interest or a
carried working interest, subject in most cases, however, to the drilling of one or more wells or other performance by the prospective assignee as a condition of the assignment. 

(i) The “General Partner’s Minimum Capital Contribution” is that amount equal to the total of
(i) all Partnership costs and expenses charged to its account from the time of the formation of the Partnership through December 31, 2011, plus (ii) the General Partner’s estimate of the total Leasehold Acquisition Costs and
Drilling Costs expected to be incurred by the Partnership subsequent to December 31, 2011, minus (iii) the amount, if any, of the unexpended Aggregate Subscription at December 31, 2011. 

(j) The “General Partner’s Percentage” is that percentage determined by dividing the amount
of the General Partner’s Minimum Capital Contribution by the total of (i) the General Partner’s Minimum Capital Contribution plus (ii) the Aggregate Subscription. 

(k) “Leasehold Acquisition Costs” with respect to properties, if any, acquired by the Partnership
from non-affiliated parties mean the actual costs to the Partnership of and in acquiring the properties, and, with respect to properties acquired by the Partnership from the General Partner, UNIT or its affiliates, are, without duplication, the sum
of: (1) the prices paid by the General Partner, UNIT or its affiliates in acquiring an oil and gas property, including purchase option fees and charges, bonuses and penalties, if any; (2) title insurance or examination costs, broker’s
commissions, filing fees, recording costs, transfer taxes, if any, and like charges incurred in connection with the acquisition of such property; (3) a pro rata portion of the actual, necessary and reasonable expenses of the General Partner,
UNIT or its affiliates for seismic and geophysical services; (4) rentals, shut-in royalties and ad valorem taxes paid by the General Partner, UNIT or its affiliates with respect to such property to the date of its transfer to the Partnership;
(5) interest and points actually incurred on funds used by the General Partner, UNIT or its affiliates to acquire or maintain such property; and (6) such portion of the General Partner’s, UNIT’s or its affiliates’
reasonable, necessary and actual expenses for geological, engineering, drafting, accounting, legal and other like services allocated to the acquisition, operations and maintenance of the property in accordance with generally accepted industry
practices, except for expenses in connection with the past drilling of wells which are not producers of sufficient quantities of oil or gas to make commercially reasonable their continued operations, and provided that the costs and expenses
enumerated in (4), (5) and (6) above with respect to any particular property shall have been incurred not more than thirty-six (36) months prior to the acquisition of such property by the Partnership. In the event a fractional
undivided interest in a property is sold or transferred by the General Partner, UNIT or any affiliate to an unaffiliated third party for an amount in excess of that portion of the original cost of the property attributable to the transferred
interest, the amount of such excess shall not reduce or be offset against the amount of the Leasehold Acquisition Costs attributable to any interest in the same property which is transferred to the Partnership. 

(l) “Limited Partners” are those persons who acquire Units in the Partnership upon its formation
and those transferees of Units who are accepted as Substituted Limited Partners. The General Partner may also be a Limited Partner if it subscribes for Units or if it subsequently acquires Units by (i) the exercise by a Limited Partner of his
or her right of presentment; (ii) a purchase by the General Partner of the Units of a Limited Partner who defaults in the payment of any subscription installment; or (iii) any other assignment or transfer. 

  
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 (m) The “Limited Partners’ Percentage” is that
percentage determined by dividing the amount of the Aggregate Subscription by the total of (i) the General Partner’s Minimum Capital Contribution plus (ii) the Aggregate Subscription. 

(n) “Normal Retirement” means retirement under the provision of a pension or similar retirement
plan adopted by the General Partner, UNIT or any subsidiary with whom a Limited Partner is employed as in effect at the time of the employee’s retirement. 
 (o) “Oil and gas properties” are oil and gas leasehold working interests, fee interests, mineral interests, royalty interests, overriding royalty interests, production payments,
options or rights to lease or acquire such interests, geophysical exploration permits and any tangible or intangible properties or other rights incident thereto, whether real, personal or mixed. 

(p) “Operating Expenses” are expenditures made and costs incurred in producing and marketing oil
or gas from completed wells, including, in addition to labor, fuel, repairs, hauling, material, supplies, utility charges and other costs incident to or necessary for the maintenance or operation of such wells or the marketing of production
therefrom, ad valorem, severance and other such taxes (other than windfall profit taxes), insurance and casualty loss expense and compensation to well operators or others for services rendered in conducting such operations. 

(q) The General Partner and the Limited Partners are sometimes collectively referred to as the
“Partners.” 
 (r) The “Partnership Properties” are oil and gas
properties or interests therein acquired by the Partnership or properties acquired by any partnership or joint venture in which the Partnership is a partner or joint venturer, whether acquired by purchase, option exercise or otherwise. 

(s) “Partnership Revenue” refers to the Partnership’s gross revenues from all sources,
including interest income, proceeds from sales of production, the Partnership’s share of revenues from partnerships or joint ventures of which it is a member, sales or other dispositions of Partnership Properties or other Partnership assets,
provided that contributions to Partnership capital by the Partners and the proceeds of any Partnership borrowings are specifically excluded and dry-hole and bottom-hole contributions shall be treated as reductions of the costs giving rise to the
right to receive such contributions. 
 (t) “Partnership Wells” are any and all of the
oil and gas wells in which the Partnership has an interest, either directly or indirectly through any other partnership or joint venture. 
 (u) “Productive properties” are oil and gas properties that have been tested by drilling and determined to be capable of producing oil or gas in commercial quantities. 

(v) “Special Production and Marketing Costs” are costs and expenses that are not normally and
customarily incurred in connection with drilling, producing and marketing operations, including without limitation, costs incurred in constructing compressor plants and pumping stations, gasoline plants, gas or oil gathering systems, natural gas
processing plants, pipeline systems and salt water disposal systems and costs incurred in installing pressure maintenance and secondary or tertiary production projects. 

(w) “Subscription Agreement” refers to the form of Limited Partner Subscription Agreement and
Suitability Statement attached as Attachment I to this Agreement. 

  
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 (x) A “Substituted Limited Partner” is a transferee,
donee, heir, legatee or other recipient of all or any portion of a Limited Partner’s interest in the Partnership with respect to whom all conditions and consents required to become a Substituted Limited Partner under Article XIII have been
satisfied and given. 
 (y) A “Unit” is a preformation unit of limited partnership
interest of a Limited Partner in the Partnership representing a Capital Subscription of One Thousand Dollars ($1,000). 

ARTICLE III 

Purposes and Powers of the Partnership 
 3.1 The purposes of the Partnership will be to acquire productive oil and gas properties and to explore for, produce, treat, transport and market oil, gas or both, or products derived therefrom, anywhere
in the United States. It is contemplated that all or most of the Partnership’s operations will be conducted as part of the operations of the General Partner and its affiliates, but the Partnership may engage in operations on its own or in
conjunction with unaffiliated third parties. In accomplishing such purposes the Partnership may: 
 (a) acquire
oil and gas properties, either alone or in conjunction with other parties; 
 (b) conduct geological and
geophysical investigations, including, without limitation, seismic exploration, core drilling and other means and methods of exploration; 
 (c) drill, equip, complete, rework, reequip, recomplete, plug back, deepen, plug and abandon Partnership Wells as the General Partner deems advisable; 

(d) acquire and dispose of tangible lease and well equipment for use or used in connection with Partnership Wells;

 (e) employ or retain such personnel and obtain such legal, accounting, geological, geophysical, engineering
and other professional services and advice as the General Partner may deem advisable in the course of the Partnership’s operations under this Agreement; 
 (f) either pay or elect not to pay delay rentals or shut-in royalties on Partnership Properties as appropriate in the judgment of the General Partner, it being understood that the General Partner will not
be liable for failure to make correct or timely payments of delay rentals or shut-in royalties if such failure was due to any reason other than gross negligence or lack of good faith; 

(g) make or give dry-hole or bottom-hole or other contributions of oil and gas properties, money or both, to encourage
drilling by others in the vicinity of or on Partnership Properties; 
 (h) negotiate for and accept dry-hole,
bottom-hole or other contributions of oil and gas properties, cash or both, as consideration for the drilling of a Partnership Well, with oil and gas properties so acquired, if any, to become Partnership Properties; 

(i) pay all ad valorem taxes levied or assessed against the Partnership Properties, all taxes upon or measured by the
production of oil or gas or other hydrocarbons therefrom, and all other taxes (other than income taxes) directly relating to operations conducted under this Agreement; 

(j) enter into and operate pursuant to operating agreements with respect to Partnership Properties naming either the
General Partner, any of its affiliates or a third party as operator, or enter into partnership agreements with third parties whereby the Partnership may be either a general or a limited partner (including any partnerships formed or sponsored by the
General Partner or in which the General Partner may also be a partner), which operating or partnership agreements shall contain such terms, provisions and conditions as the General Partner deems appropriate; 

  
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 (k) execute all documents or instruments of any kind which the General
Partner deems appropriate for carrying out the purposes of the Partnership, including, without limitation, unitization agreements, gasoline plant contracts, recycling agreements and agreements relating to pressure maintenance and secondary or
tertiary production projects; 
 (l) purchase and establish inventories of equipment and material required or
expected to be required in connection with its operations; 
 (m) contract or enter into agreements with
unaffiliated third parties, the General Partner or its affiliates for the performance of services and the purchase and sale of material, equipment, supplies and property, both real and personal, provided, however, that any such contracts or
agreements with the General Partner or any of its affiliates shall, except as otherwise provided herein, provide for prices, fees, rates, charges or other compensation which are not greater than those available from, being paid to or charged by
unaffiliated third parties dealing at arm’s length in the same or a similar geographic area for the same or comparable services, material, equipment, supplies or property; 

(n) conduct operations either alone or as a joint venturer, co-tenant, partner or in any other manner of participation
with third persons and to enter into agreements and contracts setting forth the terms and provisions of such participation; 
 (o) borrow money from banks and other lending institutions for Partnership purposes and pledge Partnership Properties (including production therefrom) for the repayment of such loans, it being understood
that no bank or other lending institution to which the General Partner makes application for a loan will be required to inquire as to the purposes for which such loan is sought, and as between the Partnership and such bank or lending institution it
will be conclusively presumed that the proceeds of such loan are to be and will be used for purposes authorized under the terms of this Agreement; 
 (p) hold Partnership Properties in its own name or in the name of the General Partner, UNIT or any affiliate or any other party as nominee for the Partnership; 

(q) sell, relinquish, release, farm-out, abandon or otherwise dispose of Partnership Properties, including undeveloped,
productive and condemned properties; 
 (r) produce, treat, transport and market oil and gas and execute division
orders, contracts for the marketing or sale of oil, gas or other hydrocarbons and other marketing agreements; 

(s) purchase, sell or pledge payments out of production from Partnership Properties; and 

(t) perform any and all other acts or activities customary or incident to exploration for or development, production and
marketing of oil and gas. 
 ARTICLE IV 
 Partner Capital Contributions 
 4.1 The General Partner will have the
unrestricted right to admit such parties as Limited Partners as it deems advisable. By their execution of the Subscription Agreement, the Limited Partners severally agree, subject to the acceptance of their subscription by the General Partner, to be
bound by the terms hereof as Limited Partners. 

  
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 4.2 The Capital Subscriptions of the Limited Partners will be payable either (i) in
four equal installments on March 15, 2011, June 15, 2011, September 15, 2011, and December 15, 2011, respectively, or (ii) by employees so electing, through equal deductions from 2011 salary paid to the employee by
the General Partner, UNIT or its subsidiaries commencing immediately after the Effective Date. Notwithstanding the foregoing, if in the judgment of the General Partner, the entire amount of the Aggregate Subscription is not required for purposes of
conducting the business, operations and affairs of the Partnership, the General Partner may, at its sole option, elect to release the Limited Partners from the obligation to pay in one or more of the installments of their Capital Subscriptions. If
Units are acquired by a corporation or other entity, the beneficial owners of the interests therein shall be jointly and severally liable for the payment of the Capital Subscription. If an employee or director who has subscribed for Units (either
directly or through a corporation or other entity) ceases to be employed by or a director of the General Partner, UNIT or any of its subsidiaries for any reason other than death, disability or Normal Retirement prior to the time the full amount of
his or her Capital Subscription is paid, then the due date for any unpaid amount shall be accelerated so that the full amount of his or her unpaid Capital Subscription shall be due and payable on the effective date of such termination. The Capital
Subscriptions shall be legally binding obligations of the Limited Partners and any past due amounts shall bear interest at the annual rate equal to two (2) percentage points in excess of the prime rate of interest of Bank of Oklahoma, N.A.,
Tulsa, Oklahoma, or successor bank, as announced and in effect from time to time, until paid. Further, in the event a Limited Partner fails to pay any installment when due, the General Partner, at its sole option and discretion, may elect to
purchase the Units of such defaulting Limited Partner at a price equal to the total amount of the Capital Contributions actually paid into the Partnership by such defaulting Limited Partner, less the amount of any Partnership distributions that may
have been received by him or her. Such option may be exercised by the General Partner by written notice to the Limited Partner at any time after the date that the unpaid installment was due and shall be deemed exercised when the amount of the
purchase price is first tendered to the defaulting Limited Partner. The General Partner may, in its discretion, accept payments of delinquent installments but shall not be required to do so. In the event that the General Partner elects to purchase
the Units of a defaulting Limited Partner, it shall pay into the Partnership the amount of the delinquent installment (excluding any interest that may have accrued thereon) and shall pay each additional installment, if any, payable with respect to
such Units as it becomes due. By virtue of such purchase, the General Partner shall be allocated all Partnership Revenues and be charged with all Partnership costs and expenses attributable to such Units otherwise allocable or chargeable to the
defaulting Limited Partner to the extent provided in Section 13.9. 
 4.3 If the Partnership requires funds to conduct
Partnership operations during the period between any of the installments due as set forth in Section 4.2 above, then, notwithstanding the provisions of Section 5.4 below, the General Partner shall advance funds to the Partnership in an
amount equal to the funds then required to conduct such operations but in no event more than the total amount of the Aggregate Subscription remaining unpaid. With respect to any such advances, the General Partner shall receive no interest thereon
and no financing charges will be levied by the General Partner in connection therewith. The General Partner shall be repaid out of the Capital Subscription installments thereafter paid into the capital of the Partnership when due. 

4.4 Additional Assessments required by the General Partner pursuant to Section 5.3 of this Agreement will be payable in cash on such
date as the General Partner may set in its written notice, but in no event will such assessments be due earlier than thirty (30) days after the date of mailing of the notice. Notice of the General Partner’s call for Additional Assessments
shall specify the amount required, the manner in which the additional funds will be expended, the date on which such amounts are payable, and the consequences of non-payment. The General Partner will not be required to accept late payments of such
amounts, but it may in its discretion do so. 

  
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 4.5 The General Partner will contribute to the capital of the Partnership amounts equal to
the total of all costs paid by the Partnership that are charged to the General Partner’s account as such costs are incurred. 
 ARTICLE V 
 Deposit and Use of Capital Contributions and 

Other Partnership Funds 
 5.1 Until required in the conduct of the Partnership’s business, Partnership funds, including, but not limited to, Capital Contributions, Partnership Revenue and proceeds of borrowings by the
Partnership, will be deposited, with or without interest, in one or more bank accounts of the Partnership in a bank or banks selected by the General Partner or invested in short-term United States government securities, money market funds, bank
certificates of deposit or commercial paper rated as “A1” or “P1” as the General Partner, in its sole discretion, deems advisable. Any interest or other income generated by such deposits or investments will be for the
Partnership’s account. Except for Capital Contributions, Partnership funds from any of the various sources mentioned above may be commingled with other Partnership funds and with the funds of the General Partner and may be withdrawn, expended
and distributed as authorized by the terms and provisions of this Agreement. 
 5.2 The Capital Contributions of the Limited
Partners will be expended for costs incurred by the Partnership that, in accordance with the terms of this Agreement, are properly chargeable to the Limited Partners’ accounts. 

5.3 After the General Partner’s Minimum Capital Contribution has been fully expended, if the Aggregate Subscription has all been
fully expended or committed and additional funds are required in order to pay Drilling Costs, Special Production and Marketing Costs or Leasehold Acquisition Costs of productive properties which are chargeable to the Limited Partners, the General
Partner may, but shall not be required to, make one or more calls for Additional Assessments from Limited Partners pursuant to Section 4.4; provided, however, that the aggregate amount of Additional Assessments called of the Limited Partners
may not exceed $100 per Unit. The Limited Partners who do not respond will participate in production, if any, obtained from the aggregate Additional Assessments paid into the Partnership. However, the amount of the unpaid Additional Assessment shall
bear interest at the annual rate equal to two (2) percentage points in excess of the prime rate of interest of Bank of Oklahoma, N.A., Tulsa, Oklahoma, or successor bank, as announced and in effect from time to time, until paid. The Partnership
will have a lien on the defaulting Limited Partner’s interest in the Partnership and the General Partner may apply Partnership Revenue otherwise available for distribution to the defaulting Limited Partner until an amount equal to the unpaid
Additional Assessment and interest is received. Furthermore, the General Partner may satisfy such lien by proceeding with legal action to enforce the lien and the defaulting Limited Partner shall pay all expenses of collection, including interest,
court costs and a reasonable attorney’s fee. 
 5.4 After the General Partner’s Minimum Capital Contribution has been
fully expended, the General Partner may cause the Partnership to borrow funds for the purpose of paying Drilling Costs, Special Production and Marketing Costs or Leasehold Acquisition Costs of productive properties, which borrowings may be secured
by interests in the Partnership Properties and will be repaid, including interest accruing thereon, out of Partnership Revenue allocable to the accounts of the Partners on whose behalf the proceeds of such borrowings are expended. The General
Partner may, but is not required to, advance funds to the Partnership for the same purposes for which Partnership borrowings are authorized by this Section 5.4. With respect to any such advances, the General Partner shall receive interest in an
amount equal to the lesser of the interest which would be charged to the Partnership by unrelated banks on comparable loans for the same purpose or the General Partner’s interest cost with respect to such loan, where it borrows the same. No
financing charges will be levied by the General Partner in connection with any such loan. If Partnership borrowings secured by interests in the Partnership Properties and repayable 

  
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out of Partnership Revenue cannot be arranged on a basis which, in the opinion of the General Partner, is fair and reasonable, and the entire sum required to pay costs of the type referred to
above is not available from Partnership Revenue, the Partnership may elect not to drill or participate in the drilling of a well or the General Partner may dispose of the Partnership Properties upon which such operations were to be conducted by sale
(subject to any other applicable provisions of this Agreement), farm-out or abandonment. 
 5.5 The General Partner may utilize
Partnership Revenue allocable to the respective accounts of the Partners to pay any Partnership costs and expenses properly chargeable to the accounts of such Partners. 
 5.6 With respect to any Partnership activity and subject to the restrictions set forth in Sections 5.3 and 5.4 above, it shall be in the sole discretion of the General Partner whether to call for
Additional Assessments, arrange for borrowings on behalf of the Partners, utilize Partnership Revenue or sell (subject to any other applicable provisions of this Agreement), farm-out or abandon Partnership Properties. 

5.7 The Partnership Properties and production therefrom may be pledged, mortgaged or otherwise encumbered as security for borrowings by
the Partnership authorized by Section 5.4 above, provided that the holder of indebtedness arising by virtue of such borrowings may not have or acquire, at any time as a result of making any such loans, any direct or indirect interest in the
profits, capital or property of the Partnership other than as a secured creditor. 
 ARTICLE VI 

Sharing of Costs, Capital Accounts and 
 Allocation of Charges and Income 
 6.1 All costs of organizing the
Partnership and offering Units therein will be paid by the General Partner. All costs incurred in the offering and syndication of any drilling or income program formed by UPC or UNIT and its affiliates during 2011 in which the Partnership
participates as a co-general partner will also be paid by the General Partner. 
 6.2 All other Partnership costs and expenses
will be charged 99% to the accounts of the Limited Partners and 1% to the account of the General Partner until such time as the Aggregate Subscription has been fully expended. Thereafter and until the General Partner’s Minimum Capital
Contribution has been fully expended, all of such costs and expenses will be charged to the General Partner. After the General Partner’s Minimum Capital Contribution has been fully expended, such costs and expenses will be charged to the
respective accounts of the General Partner and the Limited Partners on the basis of their respective Percentages. 
 6.3 All
Partnership Revenues will be allocated between the General Partner and the Limited Partners on the basis of their respective Percentages. 
 6.4 Partnership costs, expenses and Revenues which are charged and allocated to the Limited Partners shall be charged and allocated to their respective accounts in the proportion the Units of each Limited
Partner bear to the total number of outstanding Units. 

  
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 6.5 Capital accounts shall be established and maintained for each Partner in accordance with
tax accounting principles and with valid regulations issued by the U.S. Treasury Department under subsection 704(b) (the “704 Regulations”) of the Internal Revenue Code of 1986, as amended (the “Code”). To the extent that tax
accounting principles and the 704 Regulations may conflict, the latter shall control. In connection with the establishment and maintenance of such capital accounts, the following provisions shall apply: 

(a) Each Partner’s capital account shall be (i) increased by the amount of money contributed by him or her to
the Partnership, the fair market value of property contributed by him or her to the Partnership (net of liabilities securing such contributed property that the Partnership is considered to assume or take subject to under section 752 of the Code) and
allocations to him or her of Partnership income and gain (except to the extent such income or gain has previously been reflected in his or her capital account by adjustments thereto) and (ii) decreased by the amount of money distributed to him
or her by the Partnership, the fair market value of property distributed to him or her by the Partnership (net of liabilities securing such distributed property that such Partner is considered to assume or take subject to under section 752 of the
Code) and allocations to him or her of Partnership loss, deduction (except to the extent such loss or deduction has previously been reflected in his or her capital account by adjustments thereto) and expenditures described in section 705(a)(2)(B) of
the Code. 
 (b) In the event Partnership Property is distributed to a Partner, then, before the capital account
of such Partner is adjusted as required by subsection (a) of this Section 6.5, the capital accounts of the Partners shall be adjusted to reflect the manner in which the unrealized income, gain, loss and deduction inherent in such property
(that has not been reflected in such capital accounts previously) would be allocated among the Partners if there were a taxable disposition of such property for its fair market value on the date of distribution. 

(c) If, pursuant to this Agreement, Partnership Property is reflected on the books of the Partnership at a book value that
differs from the adjusted tax basis of such property, then the Partners’ capital accounts shall be adjusted in accordance with the 704 Regulations for allocations to the Partners of depreciation, depletion, amortization, and gain or loss, as
computed for book purposes, with respect to such property. 
 (d) The Partners’ capital accounts shall be
adjusted for depletion and gain or loss with respect to the Partnership’s oil or gas properties in whichever of the following manners the General Partner determines is in the best interests of the Partners: 

(i) the Partners’ capital accounts shall be reduced by a simulated depletion allowance computed on each oil or gas
property using either the cost depletion method or the percentage depletion method (without regard to the limitations under the Code which could apply to less than all Partners); provided, however, that the choice between the cost depletion method
and the simulated depletion method shall be made on a property-by-property basis in the first taxable year of the Partnership for which such choice is relevant for an oil or gas property, and such choice shall be binding for all Partnership taxable
years during which such oil or gas property is held by the Partnership. Such reductions for depletion shall not exceed the aggregate adjusted basis allocated to the Partners with respect to such oil or gas property. Such reductions for depletion
shall be allocated among the Partners’ capital accounts in the same proportions as the adjusted basis in the particular property is allocated to each Partner. Upon the taxable disposition of an oil or gas property by the Partnership, the
Partnership’s simulated gain or loss shall be determined by subtracting its simulated adjusted basis (aggregate adjusted tax basis of the Partners less simulated depletion allowances) in such property from the amount realized on such
disposition and the Partners’ capital accounts shall be increased or reduced, as the case may be, by the amount of the simulated gain or loss on such disposition in proportion to the Partners’ allocable shares of the total amount realized
on such disposition, or 
 (ii) the Partnership shall reduce the capital account of each Partner in an amount
equal to such Partner’s depletion allowance with respect to each oil or gas property of the Partnership (for the Partner’s taxable year that ends within the Partnership’s taxable year), but such reductions for depletion shall not
exceed the adjusted basis allocated to such 

  
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Partner with respect to such property. Upon the taxable disposition of an oil or gas property by the Partnership, the capital account of each Partner shall be reduced or increased, as the case
may be, by the amount of the difference between such Partner’s allocable share of the total amount realized on such disposition and such Partner’s remaining adjusted tax basis in such property. 

(e) For purposes of determining the capital account balance of any Partner as of the end of any Partnership taxable year
for purposes of Subsection 6.6(f) hereof, such Partner’s capital account shall be reduced by: 
 (i)
adjustments that, as of the end of such year, reasonably are expected to be made to such Partner’s capital account pursuant to paragraph (b)(2)(iv)(k) of the 704 Regulations for depletion allowances with respect to oil and gas properties of the
Partnership, 
 (ii) allocations of loss and deduction that, as of the end of such year, reasonably are expected
to be made to such Partner pursuant to Code section 704(e)(2), Code section 706(d), and paragraph (b)(2)(ii) of section 1.751-1 of regulations promulgated under the Code, and 

(iii) distributions that, as of the end of such year, reasonably are expected to be made to such Partner to the extent
they exceed offsetting increases to such Partner’s capital account that reasonably are expected to occur during (or prior to) the Partnership taxable years in which such distributions reasonably are expected to be made. 

6.6 With respect to the various allocations of Partnership income, gain, loss, deduction and credit for federal income tax purposes, it
is hereby agreed as follows: 
 (a) To the extent permitted by law, all charges, deductions and losses shall be
allocated for federal income tax purposes in the same manner as the costs in respect of which such charges, deductions and losses are charged to the respective accounts of the Partners. The Partners bearing the costs shall be entitled to the
deductions (including, without limitation, cost recovery allowances, depreciation and cost depletion) and credits that are attributable to such costs. 
 (b) The Partnership shall allocate to each Partner his or her portion of the adjusted basis in each depletable Partnership Property as required by Section 613A(c)(7)(D) of the Code based upon the
interest of said Partner in the capital of the Partnership as of the time of the acquisition of such Partnership Property. To the extent permitted by the Code, such allocation shall be based upon said Partner’s interest (i) in the
Partnership capital used to acquire the property, or (ii) in the adjusted basis of the property if it is contributed to the Partnership. If such allocation of basis is not permitted under the Code, then basis will be allocated in the
permissible manner which the General Partner deems will most closely achieve the result intended above. 
 (c)
Partnership Revenue shall be allocated for federal income tax purposes in the same manner as it is allocated to the respective accounts of the Partners pursuant to Sections 6.3 and 6.4 above. 

(d) Depreciation or cost recovery allowance recapture and recapture of intangible drilling and development costs, if any,
due as a result of sales or dispositions of assets shall be allocated in the same proportion that the depreciation, cost recovery allowances or intangible drilling and development costs being recaptured were allocated. 

(e) Notwithstanding anything to the contrary stated herein, 

(i) there shall be allocated first to other Limited Partners and then to the General Partner any item of loss, deduction,
credit or allowance that, but for this Subsection 6.6(e), would have been allocated to any Limited Partner that is not obligated to restore 

  
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any deficit balance in such Limited Partner’s capital account and would have thereupon caused or increased a deficit balance in such Limited Partner’s capital account as of the end of
the Partnership’s taxable year to which such allocation related (after taking into consideration the numbered items specified in Subsection 6.5(e) hereof); 
 (ii) any Limited Partner that is not obligated to restore any deficit balance in such Limited Partner’s capital account who unexpectedly receives an adjustment, allocation or distribution specified
in Subsection 6.5(e) hereof shall be allocated items of income and gain in an amount and manner sufficient to eliminate such deficit balance as quickly as possible; and 

(iii) in the event any allocations of loss, deduction, credit or allowance are made to a Limited Partner or the General
Partner pursuant to clause (i) of this Subsection 6.6(e), then such Limited Partner and/or the General Partner shall be subsequently allocated all items of income and gain pro rata as they were allocated the item(s) of loss, deduction, credit
or allowance under such clause (i) until the aggregate amount of such allocations of income and gain is equal to the aggregate amount of any such allocations of loss, deduction, credit or allowance allocated to such Partner(s) pursuant to
clause (i) of this Subsection 6.6(e). 
 (f) Notwithstanding any other provision of this Agreement, if,
under any provision of this Agreement, the capital account of any Partner is adjusted to reflect the difference between the basis to the Partnership of Partnership Property and such property’s fair market value, then all items of income, gain,
loss and deduction with respect to such property shall be allocated among the Partners so as to take account of the variation between the basis of such property and its fair market value at the time of the adjustment to such Partner’s capital
account in accordance with the requirements of subsection 704(c) of the Code, or in the same manner as provided under subsection 704(c) of the Code. 
 6.7 Notwithstanding anything to the contrary that may be expressed or implied in this Agreement, the interest of the General Partner in each material item of Partnership income, gain, loss, deduction or
credit shall be equal to at least one percent of each such item at all times during the existence of the Partnership. In determining the General Partner’s interest in such items, Units owned by the General Partner shall not be taken into
account. 
 6.8 Except as provided in subsections (a) through (d) of this Section 6.8, in the case of a change in
a Partner’s interest in the Partnership during a taxable year of the Partnership, all Partnership income, gain, loss, deduction or credit allocable to the Partners shall be allocated to the persons who were Partners during the period to which
such item is attributable in accordance with the Partners’ interests in the Partnership during such period regardless of when such item is paid or received by the Partnership. 

(a) With respect to certain “allocable cash basis items” (as such term is defined in the Code) of Partnership
Revenue, gain, loss, deduction or credit, if, during any taxable year of the Partnership there is change in any Partner’s interest in the Partnership, then, except to the extent provided in regulations prescribed under Section 706 of the
Code, each Partner’s allocable share of any “allocable cash basis item” shall be determined by (i) assigning the appropriate portion of each such item to each day in the period to which it is attributable, and
(ii) allocating the portion assigned to any such day among the Partners in proportion to their interests in the Partnership at the close of such day. 
 (b) If, by adhering to the method of allocation described in the immediately preceding subsection of this Section 6.8, a portion of any “allocable cash basis item” is attributable to any
period before the beginning of the Partnership taxable year in which such item is received or paid, such portion shall be (i) assigned to the first day of the taxable year in which it is received or paid, and (ii) allocated among the
persons who were Partners in the Partnership during the period to which such portion is attributable in accordance with their interests in the Partnership during such period. 

  
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 (c) If any portion of any “allocable cash basis item” paid or
received by the Partnership in a taxable year is attributable to a period after the close of that taxable year, such portion shall be (i) assigned to the last day of the taxable year in which it is paid or received, and (ii) allocated
among the persons who are Partners in proportion to their interests in the Partnership at the close of such day. 

(d) If any deduction is allocated to a person with respect to an “allocable cash basis item” attributable to a
period before the beginning of the Partnership taxable year and such person is not a Partner of the Partnership on the first day of the Partnership taxable year, such deduction shall be capitalized by the Partnership and treated in the manner
provided for in Section 755 of the Code. 
 ARTICLE VII 

Fiscal Year, Accountings and Reports 
 7.1 Unless the Code requires otherwise, the fiscal year of the Partnership will be the calendar year and the books of the Partnership will be kept in accordance with usual and customary accounting
practices on the accrual method. 
 7.2 Within sixty (60) days after the end of each quarter of each Partnership fiscal
year, each person who was a Limited Partner during such period will be furnished a report setting forth the source and disposition of Partnership funds during the quarter. 
 7.3 Not later than the end of the fiscal year in which all Partnership Wells are drilled and completed, and sufficient production history has been obtained on Partnership Wells to evaluate properly the
reserves attributable thereto, the General Partner will make an evaluation of Partnership Properties as of the last day of such fiscal year. The report shall include an estimate of the total oil and gas proven reserves of the Partnership and the
dollar value thereof and the value of the Limited Partner’s interest in such reserve value. It shall also contain an estimate of the present worth of the reserves. Each Limited Partner will receive a summary statement of such report reflecting
the Limited Partners’ interest in such reserve value. 
 ARTICLE VIII 

Tax Returns and Elections 
 8.1 Unless the Code requires otherwise, the General Partner will cause the Partnership to elect the calendar year as its taxable year and will timely file all Partnership income tax returns required to be
filed by the jurisdictions in which the Partnership conducts business or derives income. By March 15 of each year or as soon thereafter as practicable, the General Partner will furnish all available information necessary for inclusion in the
income tax returns of each person who was a Limited Partner during the prior fiscal year. The General Partner shall be the “Tax Matters Partner” for the Partnership pursuant to the provisions of Section 6231 of the Code subject to the
provisions of Section 10.22 below. 
 8.2 The Partnership will elect to deduct intangible drilling and development costs
currently as an expense for income tax purposes and will elect to use the available depreciation method which, in the General Partner’s judgment, is in the best interest of the Partners. 

8.3 The General Partner shall have the right in its sole discretion at any time to make or not to make such other elections as are
authorized or permitted by any law or regulation for income tax purposes (including any election under Section 754 of the Code). 

  
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 ARTICLE IX 
 Distributions 
 9.1 The Partnership’s available cash will be
distributed to the Limited Partners and the General Partner in the same proportions that Partnership Revenue has been allocated to them after giving effect to previous distributions and to portions of such revenue theretofore used or retained to pay
costs incurred or expected to be incurred in conducting Partnership operations or to repay borrowings theretofore or expected to be thereafter obtained by the Partnership. Within forty-five (45) days after the end of each calendar quarter, the
General Partner will determine the amount of cash available for distribution to the Limited Partners and will distribute such amount, if any, as promptly thereafter as reasonably possible. Distributions of cash to the General Partner may be at any
time the General Partner determines there is cash available therefor. The General Partner’s determination of the cash available for distribution will be conclusive and binding upon all Partners. All Partnership funds distributed to the Limited
Partners shall be distributed to the persons who were record holders of Units on the day on which the distribution is made. 

ARTICLE X 

Rights, Duties and Obligations of the General Partner 
 10.1 Subject to the limitations of this Agreement, the General Partner will have full, exclusive and complete discretion in the management and control of the business of the Partnership and will make all
decisions affecting its business and affairs or the Partnership Properties. The General Partner will have, subject to the provisions of this Article X, full power and authority to take any action described in Article III above and execute and
deliver in the name of and on behalf of the Partnership such documents or instruments as the General Partner deems appropriate for the conduct of Partnership business. No person, firm or corporation dealing with the Partnership will be required to
inquire into the authority of the General Partner to take any action or make any decision. 
 10.2 The General Partner will
perform the duties imposed upon it under this Agreement in an efficient and businesslike manner with due caution and in accordance with established practices of the oil and gas industry, but the General Partner shall not be liable, responsible or
accountable in damages or otherwise to the Partnership or any of the Partners for, and the Partnership shall indemnify, defend against and save harmless the General Partner, from any expense (including attorneys’ fees), loss or damage incurred
by reason of any act or omission performed or omitted in good faith on behalf of the Partnership or the Partners, and in a manner reasonably believed by the General Partner to be within the scope of the authority granted by this Agreement and in the
best interests of the Partnership or the Partners, provided that the General Partner is not guilty of gross negligence or willful misconduct with respect to such acts or omissions, and further provided that the satisfaction of any indemnification
and any saving harmless shall be from and limited to Partnership assets including insurance proceeds, if any, and no Partner shall have any personal liability on account thereof. For purposes of this Section 10.2 only, the term General Partner
includes the General Partner, affiliates of the General Partner and any officer, director or employee of the General Partner or any of its affiliates such that all of such parties are covered by the indemnities provided herein. 

10.3 The General Partner will utilize its organization and employees and will hire outside consultants for the Partnership as necessary
in order to provide experienced, qualified and competent personnel to conduct the Partnership’s business. With certain limited exceptions it is the intent of the Partners that the Partnership participate as a co-general partner of any oil and
gas drilling or income programs, or both, formed by the General Partner or UNIT for third party investors during 2011 and to participate on a proportionate working interest basis in each producing oil and gas lease acquired and in the drilling of
each oil and gas well commenced by the General Partner or UNIT for its own account during the period from the later of January 1, 2011 or the Effective Date through December 31, 2011 (except for wells, if any, (i) drilled outside of
the 48 contiguous United States; (ii) drilled as part of 

  
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secondary or tertiary recovery operations which were in existence prior to the formation of the Partnership; (iii) drilled by third parties under farm-out or similar arrangements with the
General Partner or UNIT or whereby the General Partner or UNIT may be entitled to an overriding royalty, reversionary or other similar interest in the production from such wells but is not obligated to pay any of the Drilling Costs thereof;
(iv) acquired by UNIT or the General Partner through the acquisition by UNIT or the General Partner of, or merger of UNIT or the General Partner with, other companies; or (v) with respect to which the General Partner does not believe that
the potential economic return therefrom justifies the costs of participation by the Partnership). 
 10.4 The General Partner,
UNIT or any affiliate thereof will transfer to the Partnership interests in oil and gas properties comprising the spacing unit on which a Partnership Well is located or is to be drilled for the separate account of the Partnership, provided that no
broker’s commissions or fees of a similar nature will be paid in connection with any such transfer and the consideration paid by the Partnership will be equal to the Leasehold Acquisition Costs of the property so transferred. If the size of a
spacing unit on which a Partnership Well is located is ever reduced or increased well density is permitted thereon, the Partnership will not be entitled to any reimbursement or recoupment of any portion of the Leasehold Acquisition Costs paid with
respect thereto notwithstanding the provisions of Section 10.7 below. 
 10.5 With respect to certain transactions
involving Partnership Properties, it is hereby agreed as follows: 
 (a) A sale, transfer or conveyance by the
General Partner or any affiliate of less than its entire interest in such property is prohibited unless (i) the interest retained by the General Partner or its affiliate is a proportionate working interest, (ii) the respective obligations
of the General Partner or its affiliate and the Partnership are substantially the same proportionately as those of the General Partner or its affiliate at the time it acquired the property and (iii) the Partnership’s interest in revenues
will not be less than the proportionate interest therein of the General Partner or its affiliate when it acquired the property. The General Partner or its affiliate may retain the remaining interest for its own account or it may sell, transfer,
farm-out or otherwise convey all or a portion of such remaining interest to non-affiliated industry members. In connection with any such sale, transfer, farm-out or other conveyance of such interest to non-affiliated industry members, which may
occur either before or after the transfer of the interests in the same properties to the Partnership, the General Partner or its affiliate may realize a profit on the interests or may be carried to some extent with respect to its cost obligations in
connection with any drilling on such properties and any such profit or interest will be strictly for the account of the General Partner and the Partnership will have no claim with respect thereto. 

(b) The General Partner or its affiliates may not retain any overrides or other burdens on property conveyed to the
Partnership (other than overriding royalty interests granted to geologists and other persons employed or retained by the General Partner or its affiliates). 
 10.6 The General Partner will cause the Partnership Properties to be acquired in accordance with the customs of the oil and gas industry in the area. The Partnership will be required to do only such title
work with respect to its oil and gas properties as the General Partner in its sole judgment deems appropriate in light of the area, any applicable drilling or expiration dates and any other material factors. 

10.7 Partnership Properties shall be transferred to the Partnership after the decision to acquire a productive property or the commitment
to drill a Partnership Well thereon has been made. The Partnership shall acquire interests in only those properties of the General Partner or UNIT which comprise the spacing unit on which the Partnership Well is drilled or on which a producing
Partnership Well is located. If a spacing unit on which a Partnership Well is drilled or located is ever reduced, or any subsequent well in which the Partnership has no interest is drilled thereon, the Partnership will have no interest in any such
subsequent or additional wells drilled on properties which were a part of the original spacing unit unless any such additional well is commenced during 2011 or is drilled by a drilling or 

  
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income program of which the Partnership is a partner. Likewise if UNIT, UPC or any affiliate, including any oil and gas partnership subsequently formed for investment or participation by
employees, directors and/or consultants of UNIT or any of its subsidiaries, acquires additional interests in Partnership Wells after 2011 the Partnership generally will not be entitled to participate in the acquisition of such additional interests.
In addition, if a Partnership Well drilled on a spacing unit is dry or abandoned, the Partnership will not have an interest in any subsequent or additional well drilled on the spacing unit unless it is commenced during 2011 or is drilled by a
drilling or income program of which the Partnership is a partner. 
 10.8 The General Partner, UNIT or its affiliates will
either conduct the Partnership’s drilling and production operations and operate each Partnership Well or arrange for a third party operator to conduct such operations. The General Partner will, on behalf of the Partnership, enter into
appropriate operating agreements with other owners of Partnership Wells authorizing the General Partner, its affiliates or a third party operator to conduct such operations. The Partnership will take such action in connection with operations
pursuant to said operating agreements as the General Partner, in its sole discretion, deems appropriate and in the best interests of the Partnership, and the decision of the General Partner with respect thereto will be binding upon the Partnership.

 10.9 The General Partner will cause the Partnership to plug and abandon its dry holes and abandoned wells in accordance with
rules and regulations of the governmental regulatory body having jurisdiction. 
 10.10 The General Partner may pool or unitize
Partnership Properties with other oil and gas properties when such pooling or unitization is required by a governmental regulatory body, when well spacing as determined by any such body requires such pooling or unitization, or when, in the General
Partner’s opinion, such pooling or unitization is in the best interests of the Partnership. 
 10.11 The General Partner
will have authority to make and enter into contracts for the sale of the Partnership’s share of oil or gas production from Partnership Wells, including contracts for the sale of such production to the General Partner, UNIT or its affiliates;
provided, however, that the production purchased by the General Partner, UNIT or any of its affiliates will be for prices which are not less than the highest posted price (in the case of crude oil production) or prevailing price (in the case of
natural gas production) in the same field or area. 
 10.12 The General Partner will use its best efforts to procure and
maintain for the Partnership, and at its expense, such insurance coverage with responsible companies as may be reasonably available for such premium costs as would not be considered to be unreasonably high or prohibitive with respect to each item of
coverage and as the General Partner considers necessary for the protection of the Partnership and the Partners. The coverage will be in such amounts and will cover such risks as the General Partner believes warranted by the operations conducted
hereunder. Such risks may include but will not necessarily be limited to public liability and automobile liability, each covering bodily injury, death and property damage, workmen’s compensation and employer’s liability insurance and
blowout and control of well insurance. 
 10.13 In order to conduct properly the business of the Partnership, and in order to
keep the Partners properly informed, the General Partner will: 
 (a) maintain adequate records and files
identifying the Partnership Properties and containing all pertinent information in regard thereto that is obtained or developed pursuant to this Agreement; 
 (b) maintain a complete and accurate record of the acquisition and disposition of each Partnership Property; 

  
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 (c) maintain appropriate books and records reflecting the Partnership’s
revenue and expense and each Partner’s participation therein; 
 (d) maintain a capital account for each
Partner with appropriate records as necessary in order to reflect each Partner’s interest in the Partnership and furnish required tax information; and 
 (e) keep the Limited Partners informed by means of written reports on the acquisition of Partnership Properties and the progress of the business and operations of the Partnership, which reports will be
rendered semi-annually and at such more frequent intervals during the progress of Partnership operations as the General Partner deems appropriate. 
 10.14 The General Partner, UNIT and the officers, directors, employees and affiliates thereof may own, purchase or otherwise acquire and deal in oil and gas properties, drill wells, conduct operations and
otherwise engage in any aspect of the oil and gas business, either for their own accounts or for the accounts of others. Each Limited Partner hereby agrees that engaging in any activity permitted by this Section 10.14 will not be considered a
breach of any duty that the General Partner, UNIT or the officers, directors, employees and affiliates thereof may have to the Partnership or the Limited Partners, and that the Partnership and the Limited Partners will not have any interest in any
properties acquired or profits which may be realized with respect to any such activity. 
 10.15 Subject to Section 12.1,
without the prior consent of Limited Partners holding a majority of the outstanding Units, the General Partner will not (i) make, execute or deliver any assignment for the benefit of the Partnership’s creditors; or (ii) contract to
sell all or substantially all of the Partnership Properties (except as permitted by Sections 10.23 and 16.4(b)). 
 10.16 In
contracting for services to and insurance coverage for the Partnership and its activities and operations, and in acquiring material, equipment and personal property on behalf of the Partnership, the General Partner will use its best efforts to
obtain such services, insurance, material, equipment and personal property at prices no less favorable than those normally charged in the same or in comparable geographic areas by non-affiliated persons or companies dealing at arm’s length. No
rebates, concessions or compensation of a similar nature will be paid to the General Partner by the person or company supplying such services, insurance, material, equipment and personal property. 

10.17 The General Partner, UNIT or its affiliates are authorized to provide equipment, materials and services to the Partnership in
connection with the conduct of its operations, provided, that the terms of any contracts between the Partnership and the General Partner, UNIT or any affiliates, or the officers, directors, employees and affiliates thereof must be no less favorable
to the Partnership than those of comparable contracts entered into, and will be at prices not in excess of those charged in the same geographical area by non-affiliated persons or companies dealing at arm’s length. Any such contracts for
services must be in writing precisely describing the services to be rendered and all compensation to be paid. 
 10.18 The
General Partner may cause the Partnership to hold Partnership Properties in the Partnership’s name, or in the name of the General Partner, UNIT, any affiliates thereof or some third party as nominee for the Partnership. If record title to a
Partnership Property is to be held permanently in the name of a nominee, such nominee arrangement will be evidenced and documented by a nominee agreement identifying the Partnership Properties so held and disclaiming any beneficial interest therein
by the nominee. 
 10.19 The General Partner will be generally liable for the debts and obligations of the Partnership, provided
that any claims against the Partnership shall be satisfied first out of the assets of the Partnership and only thereafter out of the separate assets of the General Partner. 
 10.20 The Partnership may not make any loans to the General Partner, UNIT or any of its affiliates. 

  
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 10.21 The General Partner will use its best efforts at all times to maintain its net worth
at a level that is sufficient to insure that the Partnership will be classified for federal income tax purposes as a partnership, rather than as an association taxable as a corporation, on account of the net worth of the General Partner. 

10.22 The Tax Matters Partner designated in Section 8.1 above is authorized to engage legal counsel and accountants and to incur
expense on behalf of the Partnership in contesting, challenging and defending against any audits, assessments and administrative or judicial proceedings conducted or participated in by the Internal Revenue Service with respect to the
Partnership’s operations and affairs. 
 10.23 At any time two years or more after the Partnership has completed
substantially all of its property acquisition, drilling and development operations, the General Partner may, without the vote, consent or approval of the Limited Partners, cause all or substantially all of the oil and gas properties and other assets
of the Partnership to be sold, assigned or transferred to, or the Partnership merged or consolidated with, another partnership or a corporation, trust or other entity for the purpose of combining the assets of two or more of the oil and gas
partnerships formed for investment or participation by employees, directors and/or consultants of UNIT or any of its subsidiaries; provided, however, that the valuation of the oil and gas properties and other assets of all such participating
partnerships for purposes of such transfer or combination shall be made on a consistent basis and in a manner which the General Partner and UNIT believe is fair and equitable to the Limited Partners. As a consequence of any such transfer or
combination, the Partnership shall be dissolved and terminated pursuant to Article XVI hereof and the Limited Partners shall receive partnership interests, stock or other equity interests in the transferee or resulting entity. 

ARTICLE XI 

Compensation and Reimbursements 
 11.1 For the General Partner’s services performed as operator of productive Partnership Wells located on Partnership Properties and as operator during the drilling of Partnership Wells, the
Partnership will compensate the General Partner at rates no higher than those normally charged in the same or a comparable geographic area by non-affiliated persons or companies dealing at arm’s length. The General Partner will not receive
compensation for such services performed in connection with the operation of Partnership Wells operated by third party operators, but such third party operators will be compensated as provided in the operating agreements in effect with respect to
such wells and the Partnership will pay its proportionate share of such compensation. 
 11.2 The General Partner will be
reimbursed by the Partnership out of Partnership Revenues for that portion of its general and administrative overhead expense that is attributable to its conduct of the actual and necessary business, affairs and operations of the Partnership. The
General Partner’s general and administrative overhead expenses will be determined in accordance with industry practices. The allocable costs and expenses will include all customary and routine legal, accounting, geological, engineering, travel,
office rent, telephone, secretarial, salaries, data processing, word processing and other incidental reasonable expenses necessary to the conduct of the Partnership’s business and generated by the General Partner or allocated to it by UNIT, but
will not include filing fees, commissions, professional fees, printing costs and other expenses incurred in forming the Partnership or offering interests therein. Also excluded will be any general and administrative overhead expense of the General
Partner or UNIT which may be attributable to its services as an operator of Partnership Wells for which it receives compensation pursuant to Section 11.1 above. The portion of the General Partner’s general and administrative overhead
expense to be reimbursed by the Partnership with respect to any particular period will be determined by allocating to the Partnership that portion of the General Partner’s total general and administrative overhead expense incurred during such
period which is equal to the ratio of the Partnership’s total expenditures compared to the total expenditures by the General Partner for its own account. The portion of such general and administrative overhead expense reimbursement which is


  
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charged to the Limited Partners may not exceed an amount equal to 3% of the Aggregate Subscription during the first 12 months of the Partnership’s operations, and in each succeeding
twelve-month period, the lesser of (a) 2% of the Aggregate Subscription and (b) 10% of the total Partnership Revenue realized in such twelve-month period. Administrative expenses incurred directly by the Partnership, or incurred by the
General Partner on behalf of the Partnership and reimbursable to the General Partner, such as legal, accounting, auditing, reporting, engineering, mailing and other such fees, costs and expenses are not to be deemed a part of the general and
administrative expense of the General Partner which is to be reimbursed pursuant to this Section 11.2 and the amounts thereof will not be subject to the limitations described in the preceding sentence. 

ARTICLE XII 

Rights and Obligations of Limited Partners 
 12.1 The Limited Partners, in their capacity as such, cannot transact any business for the Partnership or take part in the control of its business or management of its affairs. Limited Partners will have
no power to execute any agreements on behalf of, or otherwise bind or commit, the Partnership. They may give consents and approvals as herein provided and exercise the rights and powers granted to them in this Agreement, it being understood that the
exercise of such rights and powers will be deemed to be matters affecting the basic structure of the Partnership and not the exercise of control over its business; provided, however, that exercise of any of the rights and powers granted to the
Limited Partners in Sections 10.15, 12.3, 14.1, 16.1 and 18.1 will not be authorized or effective unless prior to the exercise thereof the General Partner is furnished an opinion of counsel for the Partnership or an order or judgment of any court of
competent jurisdiction to the effect that the exercise of such rights or powers (i) will not be deemed to evidence that the Limited Partners are taking part in the control of or management of the Partnership’s business and affairs,
(ii) will not result in the loss of any Limited Partner’s limited liability and (iii) will not result in the Partnership being classified as an association taxable as a corporation or a publicly traded partnership for federal income
tax purposes. 
 12.2 The Limited Partners will not be personally liable for any debts or losses of the Partnership. Except as
otherwise specifically provided herein, no Partner will be responsible for losses of any other Partners. 
 12.3 Except as
otherwise provided in this Agreement, no Limited Partner will be entitled to the return of his contribution. Distributions of Partnership assets pursuant to this Agreement may be considered and treated as returns of contributions if so designated by
law or, subject to Section 12.1, by agreement of the General Partner and Limited Partners holding a majority of the outstanding Units. The value of a Limited Partner’s undistributed contribution determined for the purposes of
Section 39 of the Act at any point in time shall be his or her percentage of the amount of the Partnership’s stated capital allocated to the Limited Partners as reflected in the financial statements of the Partnership as of such point in
time. No Partner will receive any interest on his or her contributions and no Partner will have any priority over any other Partner as to the return of contributions. 
 ARTICLE XIII 
 Transferability of Limited Partner’s Interest

 13.1 Notwithstanding the provisions of Section 13.3, no sale, exchange, transfer or assignment of a Limited
Partner’s interest in the Partnership may be made unless in the opinion of counsel for the Partnership, 

(a) such sale, exchange, transfer or assignment, when added to the total of all other sales, exchanges, transfers or
assignments of interests in the Partnership within the preceding 12 months, would not result in the Partnership being considered to have terminated within the meaning of Section 708 of the Code (provided, however, that this condition may be
waived by the General Partner in its discretion); 

  
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 (b) such sale, exchange, transfer or assignment would not violate, or cause
the offering of the Units to be violative of, the Securities Act of 1933, as amended, or any state securities or “blue sky” laws (including any investor suitability standards) applicable to the Partnership or the interest to be sold,
exchanged, transferred or assigned; and 
 (c) such sale, exchange, transfer or assignment would not cause the
Partnership to lose its status as a partnership for federal income tax purposes, and said opinion of counsel is delivered in writing to the Partnership prior to the date of the sale, exchange, transfer or assignment. 

13.2 In no event shall all or any part of an interest in the Partnership be assigned or transferred to a minor (except in trust or
pursuant to the Uniform Transfers to Minors Act) or an incompetent (except in trust), except by will or intestate succession. 

13.3 Except for transfers or assignments (in trust or otherwise) by a Limited Partner of all or any part of his or her interest in the
Partnership 
 (a) to the General Partner, 

(b) to or for the benefit of himself or herself, his or her spouse, or other members of his or her immediate family
sharing the same household, 
 (c) to a corporation or other entity in which all of the beneficial owners are
Limited Partners or assigns permitted in (a) and (b) above, or 
 (d) by the General Partner to any
person who at the time of such transfer is an employee of the General Partner, UNIT or its subsidiaries, 
 no Limited Partner’s Units or
any portion thereof may be sold, assigned or transferred except by reason of death or operation of law. 
 13.4 If a Limited
Partner dies, his or her executor, administrator or trustee, or, if he or she is adjudicated incompetent, his or her committee, guardian or conservator, or, if he or she becomes bankrupt, the trustee or receiver of his or her estate, shall have all
the rights of a Limited Partner for the purpose of settling or managing his or her estate and such power as the deceased, incapacitated or bankrupt Limited Partner possessed to assign all or any part of his or her interest and to join with such
assignee in satisfying conditions precedent to such assignee’s becoming a Substituted Limited Partner. 
 13.5 The
Partnership shall not recognize for any purpose any purported sale, assignment or transfer of all or any fraction of the interest of a Limited Partner in the Partnership, unless the provisions of Section 13.1 shall have been complied with and
there shall have been filed with the Partnership a written and dated notification of such sale, assignment or transfer in form satisfactory to the General Partner, executed and acknowledged by both the seller, assignor or transferor and the
purchaser, assignee or transferee and such notification (i) contains the acceptance by the purchaser, assignee or transferee of all of the terms and provisions of this Agreement and (ii) represents that such sale, assignment or transfer
was made in accordance with all applicable laws and regulations. Any sale, assignment or transfer shall be recognized by the Partnership as effective on the date of such notification if the date of such notification is within thirty (30) days
of the date on which such notification is filed with the Partnership, and otherwise shall be recognized as effective on the date such notification is filed with the Partnership. 

13.6 Any Limited Partner who shall assign all of his or her interest in the Partnership shall cease to be a Limited Partner, except that,
unless and until a Substituted Limited Partner is admitted in his or her stead, such assigning Limited Partner shall retain the statutory rights of the assignor of a Limited Partner’s interest under the Act. 

  
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 13.7 A person who is the assignee of all or any fraction of the interest of a Limited
Partner, but does not become a Substituted Limited Partner and desires to make a further assignment of such interest, shall be subject to all the provisions of this Article XIII to the same extent and in the same manner as any Limited Partner
desiring to make an assignment of his or her interest. 
 13.8 No Limited Partner shall have the right to substitute a
purchaser, assignee, transferee, donee, heir, legatee, distributee or other recipient of all or any portion of such Limited Partner’s interest in the Partnership as a Limited Partner in his or her place. Any such purchaser, assignee,
transferee, donee, legatee, distributee or other recipient of an interest in the Partnership shall be admitted to the Partnership as a Substituted Limited Partner only with the consent of the General Partner, which consent shall be granted or
withheld in the sole and absolute discretion of the General Partner and may be arbitrarily withheld, and only by an amendment to this Agreement or the certificate of limited partnership duly executed and recorded in the proper records of each
jurisdiction in which the Partnership owns mineral interests and filed in the proper records of the State of Oklahoma. Any such consent by the General Partner shall be binding and conclusive without the consent of any Limited Partners and may be
evidenced by the execution of the General Partner of an amendment to this Agreement or the certificate of limited partnership, evidencing the admission of such person as a Substituted Limited Partner. 

13.9 No person shall become a Substituted Limited Partner until such person shall have: 

(a) become a party to, and adopted all of the terms and conditions of, this Agreement; 

(b) if such person is a corporation, partnership or trust, provided the General Partner with evidence satisfactory to
counsel for the Partnership of such person’s authority to become a Limited Partner under the terms and provisions of this Agreement; and 
 (c) paid or agreed to pay the costs and expenses incurred by the Partnership in connection with such person’s becoming a Limited Partner. 
 Provided, however, that for the purpose of allocating Partnership Revenue, costs and expenses, a person shall be treated as having become, and as appearing in the records of the Partnership as, a
Substituted Limited Partner on such date as the sale, assignment or transfer was recognized by the Partnership pursuant to Section 13.5. 
 13.10 By his or her execution of his or her Subscription Agreement, each Limited Partner represents and warrants to the General Partner and to the Partnership that his or her acquisition of his or her
interest in the Partnership is made as principal for his or her own account for investment purposes only and not with a view to the resale or distribution of such interest. Each Limited Partner agrees that he or she will not sell, assign or
otherwise transfer his or her interest in the Partnership or any fraction thereof unless such interest has been registered under the Securities Act of 1933, as amended, or such sale, assignment or transfer is exempt from such registration and, in
any event, he or she will not so sell, assign or otherwise transfer his or her interest or any fraction thereof to any person who does not similarly represent, warrant and agree. 

ARTICLE XIV 

Assignments by the General Partner 
 14.1 The General Partner may not sell, assign, transfer or otherwise dispose of its interest in the Partnership except with the prior consent, subject to Section 12.1, of Limited Partners holding a
majority of the outstanding Units; provided that a sale, assignment or transfer may be effective without such consent if pursuant to a bona fide merger, any other corporate reorganization or a complete liquidation, pursuant to a sale of all or
substantially all of the General Partner’s assets (provided the purchasers of such assets agree to assume the duties and obligations of the General Partner) or a sale or transfer to UNIT or any affiliates of UNIT. If the Limited Partners’
consent to a proposed transfer is 

  
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required, the General Partner will, concurrently with the request for such consent, give the Limited Partners written notice identifying the interest to be transferred, the date on which the
transfer is to be effective, the proposed transferee and the substitute General Partner, if any. 
 14.2 Sales, assignments and
transfers of the interests in the Partnership owned by the General Partner will be subject to, and the assignee will acquire the assigned interest subject to, all of the terms and provisions of this Agreement. 

14.3 If the Limited Partners’ consent to a transfer of the General Partner’s interest in the Partnership is obtained as above
provided, or is not required, the transferee may become a substitute General Partner hereunder. The substitute General Partner will assume and agree to perform all of the General Partner’s duties and obligations hereunder and the transferring
General Partner will, upon making a proper accounting to the substitute General Partner, be relieved of any further duties or obligations hereunder with respect to Partnership operations thereafter occurring. 

ARTICLE XV 

Limited Partners’ Right of Presentment 
 15.1 After December 31, 2011, each Limited Partner will have the option, subject to the terms and conditions set forth in this Article XV, to require the General Partner to purchase all (but not less
than all) of his or her Units, provided that the option may not be exercised after the date of any notice that will effect a dissolution and termination of the Partnership pursuant to Article XVI below. Any such exercise shall be effected by written
notice thereof delivered to the General Partner. 
 15.2 Sales of Limited Partners’ Units pursuant to this Article XV will
be effective, and the purchase price for such interests will be determined, as of the close of business on the last day of the calendar year in which the Limited Partner’s notice exercising his or her option is given, or, at the General
Partner’s election, as of 7:00 o’clock A.M. on the following day. 
 15.3 The purchase price to be paid for the Units
of any Limited Partner who exercises the option granted in this Article XV will be determined in the following manner. First, future gross revenues expected to be derived from the production and sale of the proved reserves attributable to
Partnership Properties will be estimated, as of the end of the calendar year in which presentment is made, by the independent engineering firm preparing a report on the reserves of the Partnership, or if no such firm is preparing a report as of the
end of the calendar year in which the option is exercised, then by the General Partner. Next, future net revenues will be calculated by deducting anticipated expenses (including Operating Expenses and other costs that will be incurred in producing
and marketing such reserves and any gross production, excise, or other taxes, other than federal income taxes, based on the oil and gas production of the Partnership or sales thereof) from estimated future gross revenues. The price to be used in
calculating future gross revenues as well as the estimates of price and cost escalations to be used in such calculations will be those of such independent engineering firm or the General Partner, whichever is making the determination. Then the
present worth of the future net revenues will be calculated by discounting the estimated future net revenues at that rate per annum which is one (1) percentage point higher than the prime rate of interest being charged by Bank of Oklahoma,
N.A., Tulsa, Oklahoma, or any successor bank, as such prime rate of interest is announced by said bank as of the date such reserves are estimated. This amount will be reduced by an additional 25% to take into account the uncertainties attendant to
the production and sale of oil and gas reserves and other unforeseen contingencies. Estimated salvage value of tangible equipment installed on the Partnership Wells and costs of plugging and abandoning the productive Partnership Wells, both
discounted at the aforementioned rate from the expected date of abandonment, will be considered, and Partnership Properties, if any, which do not have proved reserves attributable to them but which have not been condemned will be valued at the lower
of cost or their then current market value as determined by the aforementioned independent petroleum engineering firm or General Partner, as the case may be. The Partnership’s cash on hand, prepaid expenses, accounts receivable (less a
reasonable reserve for doubtful accounts) and the market value of its 

  
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other assets as determined by the General Partner will be added to the value of the Partnership Properties thus determined, and the Partnership’s debts, obligations and other liabilities
will be deducted, to arrive at the Partnership’s net asset value for purposes of this Section 15.3. The price to be paid for the Limited Partner’s interest will be his or her proportionate share of such net asset value less 75% of the
amount of any Partnership distributions received by him or her which are attributable to sales of Partnership production since the date as of which the Partnership’s proved reserves are estimated. 

15.4 Within one hundred twenty (120) days after the end of any calendar year in which a Limited Partner exercises his or her option
to require purchase of his or her Units as provided in this Article XV, the General Partner will furnish to such Limited Partner a statement showing the price to be paid for his or her Units and evidencing that such price has been determined in
accordance with the provisions of Section 15.3 above. The statement will show which portion of the proposed purchase price is represented by the value of the proved reserves and by each of the other classes of Partnership assets and liabilities
attributable to the account of the Limited Partner. The Limited Partner will then have thirty (30) days to confirm, by further notice to the General Partner, his or her intention to sell his or her Units to the General Partner. If the Limited
Partner timely confirms his or her intention to sell, the sale will be consummated and the price paid in cash within ten (10) days after such confirmation. The General Partner will not be obligated to purchase (i) any Units pursuant to
such right if such purchase, when added to the total of all other sales, exchanges, transfers or assignments of the Units within the preceding 12 months, would result in the Partnership being considered to have terminated within the meaning of
Section 708 of the Code, would cause the Partnership to lose its status as a partnership for federal income tax purposes, or would cause the Partnership to be treated as a publicly traded partnership for federal income tax purposes, or
(ii) in any one calendar year more than 20% of the Units in the Partnership then outstanding. If less than all of the Units tendered are purchased, the interests purchased will be selected by lot. The Limited Partners whose tendered Units were
rejected by reason of the foregoing limitation shall be entitled to priority in the following year. Contemporaneously with the closing of any such sale, the Limited Partner will execute such certificates or other documents and perform such acts as
the General Partner deems necessary to effect the sale and transfer of the liquidating Limited Partner’s Units to the General Partner and to preserve the limited liability status of the Partnership under the laws of the jurisdictions in which
it is doing business. 
 15.5 As used in Sections 15.3 and 15.4 above, the term “proved reserves” shall have the
meaning ascribed thereto in Regulation S-X adopted by the Securities and Exchange Commission. 
 ARTICLE XVI

 Termination and Dissolution of Partnership 
 16.1 The Partnership will terminate automatically on December 31, 2041, unless prior thereto, subject to Section 12.1 above, the General Partner or Limited Partners holding a majority of the
outstanding Units elect to terminate the Partnership as of an earlier date. In the event of such earlier termination, ninety (90) days’ written notice will be given to all other Partners. The termination date will be specified in such
notice and must be the last day of any calendar month following expiration of the ninety (90) day period unless an earlier date is approved by Limited Partners holding a majority of the outstanding Units. 

16.2 Upon the dissolution (other than pursuant to a merger or other corporate reorganization), bankruptcy, legal disability or withdrawal
of the General Partner (other than pursuant to Section 14.1 above), the Partnership shall immediately be dissolved and terminated; provided, however, that nothing in this Agreement shall impair, restrict or limit the rights and powers of the
Partners under the laws of the State of Oklahoma and any other jurisdiction in which the Partnership is doing business to reform and reconstitute themselves as a limited partnership within ninety (90) days following the dissolution of the
Partnership either under provisions identical to those set forth herein or under any other provisions. The withdrawal, expulsion, dissolution, death, legal disability, bankruptcy or insolvency of any Limited Partner will not effect a dissolution or
termination of the Partnership. 

  
 A-25









 16.3 Upon termination of the Partnership by action of the Limited Partners pursuant to
Section 16.1 hereof or as a result of an event under Section 16.2 hereof, a party designated by the Limited Partners holding a majority of the outstanding Units will act as Liquidating Trustee. In any other case, the General Partner will
act as Liquidating Trustee. 
 16.4 As soon as possible after December 31, 2041, or the date of the notice of or event
causing an earlier termination of the Partnership, the Liquidating Trustee will begin to wind up the Partnership’s business and affairs. In this regard: 
 (a) The Liquidating Trustee will furnish or obtain an accounting with respect to all Partnership accounts and the account of each Partner and with respect to the Partnership’s assets and liabilities
and its operations from the date of the last previous audit of the Partnership to the date of such dissolution; 

(b) The Liquidating Trustee may, in its discretion, sell any or all productive and non-productive properties which, except
in the case of an election by the General Partner to terminate the Partnership prior to the tenth anniversary of the Effective Date, may be sold to the General Partner or any of its affiliates for their fair market value as determined in good faith
by the General Partner; 
 (c) The Liquidating Trustee shall: 

(i) pay all of the Partnership’s debts, liabilities and obligations to its creditors, including the General Partner;
and 
 (ii) pay all expenses incurred in connection with the termination, liquidation and dissolution of the
Partnership and distribution of its assets as herein provided; 
 (d) The Liquidating Trustee shall ascertain the
fair market value by appraisal or other reasonable means of all assets of the Partnership remaining unsold, and each Partner’s capital account shall be charged or credited, as the case may be, as if such property had been sold at such fair
market value and the gain or loss realized thereby had been allocated to and among the Partners in accordance with Article VI hereof; and 
 (e) On or as soon as practicable after the effective date of the termination, all remaining cash and any other properties and assets of the Partnership not sold pursuant to the preceding subsections of
this Section 16.4 will be distributed to the Partners (i) in proportion to and to the extent of any remaining balances in the Partners’ capital accounts and then (ii) in undivided interests to the Partners in the same proportions
that Partnership Revenues are being shared at the time of such termination, provided, that: 
 (i) the various
interests distributed to the respective Partners will be distributed subject to such liens, encumbrances, restrictions, contracts, operating agreements, obligations, commitments or undertakings as existed with respect to such interests at the time
they were acquired by the Partnership or were subsequently created or entered into by the Partnership; 
 (ii) if
interests in the Partnership Wells that are not subject to any operating agreement are to be distributed, the Partners will, concurrently with the distribution, enter into standard form operating agreements covering the subsequent operation of each
such well which will, if the termination is effected pursuant to Section 16.1 above, be in a form satisfactory to the General Partner and will name the General Partner or its designee as operator; and 

  
 A-26









 (iii) no Partner shall be distributed an interest in any asset if the
distribution would result in a deficit balance or increase the deficit balance in its capital account (after making the adjustments referred to in this Section 16.4 relating to distributions in kind). 

16.5 If the General Partner has a deficit balance in its capital account following the distribution(s) provided for in
Section 16.4(e) above, as determined after taking into account all adjustments to its capital account for the taxable year of the Partnership during which such distribution occurs, it shall restore the amount of such deficit balance to the
Partnership within ninety (90) days and such amount shall be distributed to the other Partners in accordance with their positive capital account balances. 
 16.6 Notwithstanding anything to the contrary in this Agreement, upon the dissolution and termination of the Partnership, the General Partner will contribute to the Partnership the lesser of: (a) the
deficit balance in its capital account; or (b) the excess of 1.01 percent of the total Capital Contributions of the Limited Partners over the capital previously contributed by the General Partner. 

ARTICLE XVII 
 Notices 
 17.1 All notices, consents, requests, demands, offers, reports
and other communications required or permitted shall be deemed to be given or made when personally delivered to the party entitled thereto, or when sent by United States mail in a sealed envelope, with postage prepaid, addressed, if to the General
Partner, to 7130 South Lewis, Suite 1000, Tulsa, Oklahoma 74136, and, if to a Limited Partner, to the address set forth below such Limited Partner’s signature on the counterpart of the Subscription Agreement that he or she originally executed
and delivered to the General Partner. The General Partner may change its address by giving notice to all Limited Partners. Limited Partners may change their address by giving notice to the General Partner. 

ARTICLE XVIII 
 Amendments 
 18.1 Limited Partners do not have the right to propose
amendments to this Agreement. The General Partner may propose an amendment or amendments to this Agreement by mailing to the Limited Partners a notice describing the proposed amendment and a form to be returned by the Limited Partners indicating
whether they oppose or approve of its adoption. Such notice will include the text of the proposed amendment, which will have been approved in advance by counsel for the Partnership. If, within sixty (60) days, or such shorter period as may be
designated by the General Partner, after any notice proposing an amendment or amendments to this Agreement has been mailed, Limited Partners holding a majority of the outstanding Units have properly executed and returned the form indicating that
they approve of and consent to adoption of the proposed amendment, such amendment will become effective as of the date specified in such notice, provided that no amendment which alters the allocations specified in Article VI above, changes the
compensation and reimbursement provisions set forth in Article XI above or is otherwise materially adverse to the interests of the Limited Partners will become effective unless approved by all Limited Partners. If an amendment does become effective,
all Partners will promptly evidence such effectiveness by executing such certificates and other instruments as the General Partner may deem necessary or appropriate under the laws of the jurisdictions in which the Partnership is then doing business
in order to reflect the amendment. 

  
 A-27









 ARTICLE XIX 
 General Provisions 
 19.1 This Agreement embodies the entire understanding
and agreement between the Partners concerning the Partnership, and supersedes any and all prior negotiations, understandings or agreements in regard thereto. 
 19.2 In those cases where this Agreement requires opinions to be expressed by, or actions to be approved by, counsel for Limited Partners, such counsel must be qualified and experienced in the fields of
federal income taxation and partnership and securities laws. 
 19.3 This Agreement and the Subscription Agreement may be
executed in multiple counterpart copies, each of which will be considered an original and all of which constitute one and the same instrument. 
 19.4 This Agreement will be deemed to have been executed and delivered in the State of Oklahoma and will be construed and interpreted according to the laws of that State. 

19.5 This Agreement and all of the terms and provisions hereof will be binding upon and will inure to the benefit of the Partners and
their respective heirs, executors, administrators, trustees, successors and assigns. 
 EXECUTED in the name of and on
behalf of the undersigned General Partner this              day of January, 2011 but effective as of the Effective Date. 

 

									
		 		 		 	“General Partner”
		 		 		 	UNIT PETROLEUM COMPANY
	Attest:	 		 		 	
					
	By	 	  
	 		 	By	 	  

		 	 Mark E. Schell, Secretary
	 		 		 	 Larry D. Pinkston, President



  
 A-28









 LIMITED PARTNER SUBSCRIPTION AGREEMENT AND 

SUITABILITY STATEMENT 
 (ALL INFORMATION WILL BE TREATED CONFIDENTIALLY) 
  

					
	Unit 2011 Employee Oil and Gas Limited Partnership	  	MUST BE RECEIVED BY:
	c/o Unit Petroleum Company	  	January 21, 2011
	7130 South Lewis Avenue, Suite 1000	  	
	Tulsa, Oklahoma 74136	  	RETURN TO:
		
		  	Attn: Mark Schell
		  	Unit 2011 Employee Oil and Gas
	RE:	  	Unit 2011 Employee Oil and	  	Limited Partnership
		  	Gas Limited Partnership	  	 7130 South Lewis Ave., Suite 1000
 Tulsa, OK 74136


 Gentlemen: 

In connection with the subscription of the undersigned for units of limited partnership interest (“Units”) in the
Unit 2011 Employee Oil and Gas Limited Partnership (the “Partnership”) which the undersigned tenders herewith to Unit Petroleum Company (the “General Partner”), the undersigned is hereby furnishing the
Partnership and the General Partner the information set forth herein below and makes the representations and warranties set forth below, to indicate whether the undersigned is a suitable subscriber for Units in the Partnership. As a condition
precedent to investing in the Partnership, the undersigned hereby represents, warrants, covenants and agrees as follows: 
 1.
The undersigned acknowledges that he or she has received and reviewed a copy of the Private Offering Memorandum (the “Offering Memorandum”) dated December 15, 2010 of the Unit 2011 Employee Oil and Gas Limited
Partnership, relating to the offering of Units in the Partnership, and all Exhibits thereto, including the Agreement of Limited Partnership (the “Agreement”), and understands that the Units will be offered to others on the
terms and in the manner described in the Offering Memorandum. The undersigned hereby subscribes for the number of Units set forth below pursuant to the terms of the Offering Memorandum and tenders his or her Capital Subscription as required and
agrees to pay his or her Additional Assessments upon call or calls by the General Partner; and the undersigned acknowledges that he or she shall have the right to withdraw this subscription only up until the time the General Partner executes and
accepts the undersigned’s subscription and that the General Partner may reject any subscription for any reason without liability to it; and, further, the undersigned agrees to comply with the terms of the Agreement and to execute any and all
further documents necessary in connection with his or her admission to the Partnership. 
 2. The undersigned has reviewed and
acknowledges execution of the Power of Attorney set forth in the Agreement and elsewhere in this instrument. 
 3. The
undersigned is aware that no federal or state regulatory agency has made any findings or determination as to the fairness for public or private investment, nor any recommendation or endorsement, of the purchase of Units as an investment. 


  
 Attachment I
to the 
 Unit 2011 Employee Oil and Gas Limited Partnership 

Agreement of Limited Partnership 
 I-1 








 4. The undersigned recognizes the speculative nature and risks of loss associated with oil
and gas investments and that he or she may suffer a complete loss of his or her investment. The Units subscribed for hereby constitute an investment which is suitable and consistent with his or her investment program and that his or her financial
situation enables him or her to bear the risks of this investment. The undersigned represents that he or she has adequate means of providing for his or her current needs and possible personal contingencies, and that he or she has no need for
liquidity of this investment. 
 5. The undersigned confirms that he or she understands, and has fully considered for purposes
of this investment, the RISK FACTORS set forth in the Offering Memorandum and that (i) the Units are speculative investments which involve a high degree of risk of loss by the undersigned of his or her investment therein, (ii) there is a
risk that the anticipated tax benefits under the Agreement could be challenged by the Internal Revenue Service or could be affected by changes in the Internal Revenue Code of 1986, as amended, the regulations thereunder or administrative or judicial
interpretations thereof thereby depriving Limited Partners of anticipated tax benefits, (iii) the General Partner and its affiliates will engage in transactions with the Partnership which may result in a profit and, in the future, may be
engaged in businesses which are competitive with that of the Partnership, and the undersigned agrees and consents to such activities, even though there are conflicts of interest inherent therein, and (iv) there are substantial restrictions on
the transferability of, and there will be no public market for, the Units and, accordingly, it may be difficult for him or her to liquidate his or her investment in the Units in case of emergency, if possible at all. 

6. The undersigned confirms that in making his or her decision to purchase the Units subscribed for, he or she has relied upon
independent investigations made by him or her (or by his or her own professional tax and other advisors) and that he or she has been given the opportunity to examine all documents and to ask questions of, and to receive answers from the General
Partner or any person(s) acting on its behalf concerning the terms and conditions of the offering or any other matter set forth in the Offering Memorandum, and to obtain any additional information, to the extent the General Partner possesses such
information or can acquire it without unreasonable effort or expense, necessary to verify the accuracy of the information set forth in the Offering Memorandum, and that no representations have been made to him or her and no offering materials have
been furnished to him or her concerning the Units, the Partnership, its business or prospects or other matters, except as set forth in the Offering Memorandum and the other materials described in the Offering Memorandum. 

7. The undersigned understands that the Units are being offered and sold under an exemption from registration provided by Sections 3(b)
and/or 4(2) of the Securities Act of 1933, as amended (the “Act”), and warrants and represents that any Units subscribed for are being acquired by the undersigned solely for his or her own account, for investment purposes
only, and are not being purchased with a view to or for the resale, distribution, subdivision or fractionalization thereof; the undersigned has no agreement or other arrangement, formal or informal, with any person to sell, transfer or pledge any
part of any Units subscribed for or which would guarantee any rights to such Units; the undersigned has no plans to enter into any such agreement or arrangement, and, consequently, he or she must bear the economic risk of the


  
 Attachment I
to the 
 Unit 2011 Employee Oil and Gas Limited Partnership 

Agreement of Limited Partnership 
 I-2 








 
investment for an indefinite period of time because the Units cannot be resold or otherwise transferred unless subsequently registered under the Act (which neither the General Partner nor the
Partnership is obligated to do), or an exemption from such registration is available and, in any event, unless transferred in compliance with the Agreement. 
 8. The undersigned further understands that the exemption under Rule 144 of the Act will not be generally available because of the conditions and limitations of such rule; that, in the absence of the
availability of such rule, any disposition by him or her of any portion of his or her investment will require compliance under the Act; and that the Partnership and the General Partner are under no obligation to take any action in furtherance of
making such exemption available. 
 9. The undersigned is aware that the General Partner will have full and complete control of
Partnership operations and that he or she must depend on the General Partner to manage the Partnership profitably; and that a Limited Partner does not have the same rights as a stockholder in a corporation or the protection which stockholders might
have, since limited partners have limited rights in determining policy. 
 10. The undersigned is aware that the General Partner
will receive compensation for its services irrespective of the economic success of the Partnership. 
 11. The undersigned
represents and warrants as follows (please mark and complete all applicable categories): 
 (a) If an individual,
the undersigned is the sole party in interest, and the undersigned is at least 21 years of age and a bona fide resident and domiciliary (not a temporary or transient resident) of the state set forth opposite his or her signature hereto; 

 

			
	             YES	 	              NO



(b) If a partnership or corporation, the undersigned meets the following: (1) the entity has not been formed for the
purposes of making this investment; (2) the entity was formed on             ; and (3) the entity has a history of investments similar to the type described in the Offering
Memorandum; 
  

			
	             YES	 	              NO



(c) The undersigned meets all suitability standards and acknowledges being aware of all legend conditions applicable to
his or her state of residence as set forth herein; 
  

			
	             YES	 	              NO



  
 Attachment I
to the 
 Unit 2011 Employee Oil and Gas Limited Partnership 

Agreement of Limited Partnership 
 I-3 








 (d)(i) The undersigned has a net worth (including home, furnishings and
automobiles) of at least five times the amount of his or her Capital Subscription, and anticipates that he or she will have adjusted gross income during the current year in an amount which will enable him or her to bear the economic risks of the
investment in the Partnership; 
  

			
	             YES	 	              NO



and 
 (ii) The undersigned is a salaried employee of Unit Corporation (“UNIT”) or one of its subsidiaries at the date of formation of the Partnership whose annual base salary for 2010
has been set at $60,000 or more, or the undersigned is a director of UNIT; 
  

			
	             YES	 	              NO



and 
 (e) The undersigned              is or              is not a citizen
of the United States. 
 12. The undersigned represents and agrees that he or she has had sufficient opportunity to make
inquiries of the General Partner in order to supplement information contained in the Offering Memorandum respecting the offering, and that any information so requested has been made available to his or her satisfaction, and he or she has had the
opportunity to verify such information. The undersigned further agrees and represents that he or she has knowledge and experience in business and financial matters, and with respect to investments generally, and in particular, investments generally
comparable to the offering, so as to enable him or her to utilize such information to evaluate the risks of this investment and to make an informed investment decision. The following is a brief description of the undersigned’s experience in the
evaluation of other investments generally comparable to the offering: 
  

 
  

 
  

 
  

 
 13. The undersigned is aware
that the Partnership and the General Partner have been and are relying upon the representations and warranties set forth in this Limited Partner Subscription Agreement and Suitability Statement, in part, in determining whether the offering meets the
conditions specified in Rules of the Securities and Exchange Commission and the exemption from registration provided by Sections 3(b) and/or 4(2) of the Act. 

  
 Attachment I
to the 
 Unit 2011 Employee Oil and Gas Limited Partnership 

Agreement of Limited Partnership 
 I-4 








 14. All of the information which the undersigned has furnished the General Partner herein or
previously with respect to the undersigned’s financial position and business experience is correct and complete as of the date of this Agreement, and, if there should be any material change in such information prior to the closing of the
offering period of the Units, the undersigned will immediately furnish such revised or corrected information to the General Partner. The undersigned agrees that the foregoing representations and warranties shall survive his or her admission to the
Partnership, as well as any acceptance or rejection of a subscription for the Units. 
 If the subscription tendered hereby of
the undersigned is accepted by the General Partner, the undersigned hereby executes and swears to the Agreement of Limited Partnership of Unit 2011 Employee Oil and Gas Limited Partnership as a Limited Partner, thereby agreeing to all the terms
thereof and duly appoints the General Partner, with full power of substitution, his or her true and lawful attorney to execute, file, swear to and record any Certificate of Limited Partnership or amendments thereto or cancellation thereof and 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 purposes necessary to implement the Partnership’s purposes. 

THE SECURITIES REPRESENTED BY THIS CERTIFICATE HAVE NOT BEEN REGISTERED UNDER THE SECURITIES ACT OF 1933, AS AMENDED, THE OKLAHOMA
SECURITIES ACT OR OTHER APPLICABLE STATE SECURITIES ACTS. THE SECURITIES HAVE BEEN ACQUIRED FOR INVESTMENT AND MAY NOT BE SOLD OR TRANSFERRED FOR VALUE IN THE ABSENCE OF AN EFFECTIVE REGISTRATION OF THEM UNDER THE SECURITIES ACT OF 1933, AS AMENDED,
AND/OR THE OKLAHOMA SECURITIES ACT, OR ANY OTHER APPLICABLE ACT, OR AN OPINION OF COUNSEL TO UNIT 2011 EMPLOYEE OIL AND GAS LIMITED PARTNERSHIP THAT SUCH REGISTRATION IS NOT REQUIRED UNDER SUCH ACT. 

The undersigned hereby subscribes for             Units (minimum
subscription: 2 Units) at a price of $1,000 per Unit for a total Capital Subscription (as defined in Article II of the Agreement) of $            , which shall be due and payable either:

 (Check One) 

                (a) in four equal installments on March 15,
2011, June 15, 2011, September 15, 2011 and December 15, 2011, respectively; or 

                (b) through equal deductions from 2011 salary of
the undersigned commencing immediately after the Effective Date (as defined in Article II of the Agreement). 

  
 Attachment I
to the 
 Unit 2011 Employee Oil and Gas Limited Partnership 

Agreement of Limited Partnership 
 I-5 









									
		 		 	RESIDENT	 		 	
	LIMITED PARTNER:	 		 	ADDRESS:	 		 	(If placing Units in the name of spouse or trustee for minor child or children, please provide name, address of such spouse or trustee and Social Security or Tax
Identification Number)
		 		 		 		 
	 *
	 		 	 *
	 		 
		 		 	  
	 		 
	 *
	 		 	  
	 		 
	Signature(s)	 		 		 		 
		 		 		 		 
	 *
	 		 	MAILING ADDRESS:	 		 
	 *
	 		 	*if different	 		 
	Please Print Name(s)	 		 		 		 	
		 		 	  
	 		 	TAX I.D. NO. OR SOCIAL
	Date: *                           
          	 		 	  
	 		 	SECURITY NO.:
		 		 	  
	 		 	
		 		 	  
	 		 	 *



 

	*	Required Field 

 THE
FOLLOWING IS TO BE COMPLETED BY THE COMPANY 
 ACCEPTED THIS             DAY OF
January, 2011. 
 UNIT 2011 EMPLOYEE OIL AND GAS LIMITED PARTNERSHIP 

 

			
	By:	 	  

		 	    Authorized Officer of Unit
		 	    Petroleum Company, General Partner

 Upon completion, an executed copy of this Limited Partner Subscription Agreement and Suitability Statement must be returned to Unit 2011 Employee Oil and Gas Limited Partnership, Attention: Mark
E. Schell, 7130 South Lewis Avenue, Suite 1000, Tulsa, Oklahoma 74136. The General Partner, after acceptance, will return a copy of the accepted Subscription Agreement to the Limited Partner. 

  
 Attachment I
to the 
 Unit 2011 Employee Oil and Gas Limited Partnership 

Agreement of Limited Partnership 
 I-6 









 

 

 303 Paseo de Peralta, Suite C  |  Santa Fe, NM 87501-1860  |  p
505-983-6497  |  f 918-586-8665  |  cwlaw.com 
 Douglas M. Rather  |  Attorney at
Law 
 p 505-983-6497  |  f 918-586-8665  |  drather@cwlaw.com 

December 30, 2010 
 Unit
Petroleum Company 
 7130 South Lewis, Suite 1000 
 Tulsa, Oklahoma 74136-5492 
  

	 	Re:	Unit 2011 Employee Oil and Gas Limited Partnership 

 Dear Sirs: 
 We have acted as counsel for Unit Petroleum Company, an Oklahoma
corporation (the “General Partner”), which will be the General Partner in the Unit 2011 Employee Oil and Gas Limited Partnership, a proposed Oklahoma limited partnership (the “Partnership”). You have requested our opinions
regarding certain federal income tax matters concerning the Partnership. 
 We have reviewed and relied upon the accuracy of the
facts and information set forth in the Private Offering Memorandum dated December 30, 2010 (the “Memorandum”), covering the offer and sale of units of limited partnership interest (“Units”) in the Partnership, the Agreement
of Limited Partnership included as Exhibit A to the Memorandum (the “Partnership Agreement”), the consolidated balance sheet of the General Partner dated October 31, 2010, and such other documents and matters as we have considered
necessary in order to render this opinion. Capitalized terms used herein have the meaning assigned to them in the Memorandum, except as otherwise specifically indicated. 
 In our examination we have assumed the authenticity of original documents, the accuracy of copies and the genuineness of signatures. We have relied upon the representations and statements of the General
Partner of the Partnership with respect to the factual determinations underlying the legal conclusions set forth herein. We have not attempted to verify independently such representations and statements. 

Please note that we are opining only as to the matters expressly set forth herein, and no opinion should be inferred as to any other
matters. We are unable to render opinions as to a number of federal income tax issues relating to an investment in Units and the operations of the Partnership. 
 The following opinion and statements are based upon the provisions of the Internal Revenue Code of 1986, as amended (the “Code”), existing and proposed regulations thereunder
(“Regulations”), current administrative rulings, and court decisions. Federal income tax law is uncertain as to many of the tax matters material to an investment in the Partnership, and it is not possible to predict with certainty how the
law will develop or how the courts will decide various issues if they are litigated. While this opinion states our views concerning the tax aspects of an investment in the Partnership, both the Internal Revenue Service (the “Service”) and
the courts may disagree with our position on certain issues. 

  
 Conner &
Winters, LLP  |  Attorneys and Counselors at Law         

	 Dallas, TX  |  Houston, TX  |  NW Arkansas  |  Oklahoma City,
OK  |  Santa Fe, NM  |  Tulsa, OK  |  Washington, DC 
	 Exhibit B 











 CONNER & WINTERS, LLP 
 Unit Petroleum Company 
 December 30, 2010 
 Page 2 
  

 Moreover, uncertainty exists concerning some of the federal income tax aspects of the
transactions being undertaken by the Partnership. Some of the tax positions to be taken by the Partnership may be challenged by the Service and there is no assurance that any such challenge will not be successful. Thus, there can be no assurance
that all of the anticipated tax benefits of an investment in the Partnership will be realized. 
 Our opinions are based upon
the facts described in the Memorandum as they have been represented to us or determined by us as of the date of the opinion. Any alteration of the facts may adversely affect the opinions rendered. In our opinion, the preponderance of the material
tax benefits, in the aggregate, will be realized by the Partners. It is possible, however, that some of the tax benefits will be eliminated or deferred to future years. 
 Compliance with Circular 230 
 The United States Treasury Department
establishes standards for tax practitioners who practice before the Internal Revenue Service (the “Service”). Those standards are set forth in a publication known as Circular 230. Circular 230 was recently revised and now requires that
written statements issued by a tax practitioner that constitute a Covered Opinion, within the meaning of Circular 230, adhere to certain standards of factual and legal due diligence, contain certain material and conform to a specific manner of
presentation. 
 We have concluded that this letter opinion (the “Letter”) constitutes a Covered Opinion. Accordingly,
the Letter is drafted in a manner designed to comply with the Covered Opinion requirements of Circular 230. We have concluded that no federal tax issue discussed in the Letter relates to a Listed Transaction within the meaning of Circular 230. We
have concluded that the tax benefits discussed in the Letter likely are being claimed in accordance with provisions of the Code and the underlying Congressional purpose and, therefore, conclude that the principal purpose of the transactions as
outlined are not tax avoidance. We have also concluded, however, that a significant purpose of the transactions may be tax avoidance, and, as set forth below, we have reached a more-likely-than-not conclusion (a greater than fifty percent
(50%) likelihood) with respect to one or more significant federal tax issues that we discuss below. We have, therefore, concluded that the Letter constitutes a Reliance Opinion within the meaning of Circular 230. 








 CONNER & WINTERS, LLP 
 Unit Petroleum Company 
 December 30, 2010 
 Page 3 
  

 Because we understand that you may use the Letter to promote, market, or recommend tax
matters addressed herein, we also have concluded that this advice may be considered a Marketed Opinion within the meaning of Circular 230. However, the Letter is not intended to be a Marketed Opinion. Therefore, as permitted in Circular 230, we are
providing the following Marketed Opinion disclaimer: 
 IMPORTANT LIMITATIONS ON TAX ASPECTS — 

MARKETED OPINION DISCLAIMER 
 In order to avoid the characterization of the Letter constituting a Marketed Opinion, we state that this advice: (i) was not intended or written by the practitioner to be used and that it cannot
be used by any taxpayer for the purpose of avoiding penalties; (ii) was written to support the promotion or marketing of the transaction or matters addressed by the written advice; and (iii) taxpayers should seek advice based on the
taxpayer’s particular circumstances from an independent tax advisor. 
 Circular 230 also provides that a Covered
Opinion which is a Limited Scope Opinion, an opinion that is limited to the federal tax issues addressed in the opinion and which does not address all of the significant federal tax issues, satisfies the Covered Opinion requirements. The Letter is a
Limited Scope Opinion. As required in Circular 230, therefore, we are providing the following Limited Scope Opinion disclosure: 

IMPORTANT LIMITATIONS ON TAX ASPECTS — 
 LIMITED SCOPE OPINION DISCLAIMER 
 The Letter is limited to the United
States federal income tax consequences addressed herein. Additional issues may exist that could affect the federal tax treatment of the transactions or matters addressed herein and the Letter does not consider or provide a conclusion with respect to
any such additional issues. The Letter was not written, and cannot be used, to avoid tax penalties with respect to any federal tax issues not addressed herein. 
 SUMMARY OF CONCLUSIONS 
 Opinions expressed: The following is a
summary of the specific opinions expressed by us with respect to the Federal Income Tax Considerations discussed herein. TO BE FULLY UNDERSTOOD, THE COMPLETE DISCUSSION OF THESE MATTERS SHOULD BE READ BY EACH PROSPECTIVE PARTNER. 

1. The material federal income tax benefits in the aggregate from an investment in the Partnership will be realized. 

2. The Partnership will be treated as a partnership for federal income tax purposes and not as a corporation, an association taxable as a
corporation or a “publicly traded partnership.” 
 3. To the extent the Partnership’s wells are timely drilled
and amounts are timely paid, the Partners will be entitled to their pro rata shares of the Partnership’s IDC paid in 2011. 








 CONNER & WINTERS, LLP 
 Unit Petroleum Company 
 December 30, 2010 
 Page 4 
  

 4. A Limited Partner’s interest will be considered a passive activity within the
meaning of Code Section 469 and losses generated therefrom will be limited by the passive activity provisions of the Code. 

5. To the extent provided herein, the Partners’ distributive shares of Partnership tax items will be determined and allocated
substantially in accordance with the terms of the Partnership Agreement. 
 No opinion expressed: Due to the lack of
authority, or the essentially factual nature of the question, we express no opinion on the following: 
 1. The impact of an
investment in the Partnership on an investor’s alternative minimum tax liability. 
 2. Whether each Partner will be
entitled to percentage depletion since such a determination is dependent upon the status of the Partner as an independent producer. 
 3. Whether any interest incurred by a Partner with respect to any borrowings to acquire a Unit will be deductible or subject to limitations on deductibility. 

4. Whether the Partnership will be treated as the tax owner of Partnership Properties acquired by the General Partner as nominee for the
Partnership. 
 General Information: Certain matters contained herein are not considered to address a material tax
consequence and are for general information, including the matters contained in sections dealing with gain or loss on the sale of Units or of property, Partnership distributions, tax audits, penalties, and state and local tax. 

Our opinions are also based upon the facts described in the Memorandum and upon certain representations made to us by the General Partner
for the purpose of permitting us to render our opinions, including the following representations with respect to the Partnership: 
 1. The Partnership Agreement to be entered into by and among the General Partner and Limited Partners and any amendments thereto will be duly executed and will be made available to any Limited Partner
upon written request. The Partnership Agreement will be duly recorded in all places required under the Oklahoma Uniform Limited Partnership Act of 2010 (the “Act”) for the due formation of the Partnership and for the continuation thereof
in accordance with the terms of the Partnership Agreement. The Partnership will at all times be operated in accordance with the terms of the Partnership Agreement, the Memorandum, and the Act. 








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 2. No election will be made by the Partnership, any of the Limited Partners, or the
General Partner to be excluded from the application of the provisions of Subchapter K of the Code. 
 3. The Partnership
will own operating mineral interests, as defined in the Code and in the Regulations, and none of the Partnership’s revenues will be from non-working interests. 
 4. In the manner required by the Code and Regulations, the General Partner will cause the Partnership to elect to deduct currently all Intangible Drilling and Development Costs. 

5. The Partnership will have a December 31 taxable year and will report its income on the accrual basis. 

6. All Partnership wells will be spudded by not later than December 31, 2010. The entire amount to be paid under any drilling and
under the operating agreements entered into by the Partnership will be attributable to Intangible Drilling and Development Costs. 
 7. Such drilling and operating agreements will be duly executed and will govern the operation of the Partnership’s wells. 
 8. At least 90% of the gross income of the Partnership will constitute income derived from the exploration, development, production, and or marketing of oil and gas. The General Partner does not believe
that any market will ever exist for the sale of Units and the General Partner will not make a market for the Units. Further, the Units will not be traded on an established securities market or the substantial equivalent thereof. 

9. There is not now pending nor, to the knowledge of the General Partner or UNIT, threatened any action, suit or proceeding by the
Internal Revenue Service under Sections 6700 or 7408 of the Internal Revenue Code relating to the promoter penalty referred to in Section 6700 of the Code with respect to any partnerships sponsored by the General Partner or UNIT. Neither
the General Partner, UNIT, nor, to the knowledge of either of them, any participant in such partnerships has received any pre-filing notifications referred to in Revenue Procedure 83-73 with respect to such partnerships or the Partnership from the
Internal Revenue Service. 
 10. The General Partner will, as nominee for the Partnership, acquire and hold title to Partnership
Properties on behalf of the Partnership; the General Partner will enter into an agency agreement before the General Partner acquires any such oil and gas properties on behalf of the Partnership; the agency agreement will reflect that the General
Partner’s acquisition of Partnership properties is on behalf of the Partnership; and the General Partner will execute assignments of all oil and gas interests acquired by it on behalf of the Partnership to the Partnership. 








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 11. The Partnership and each Partner will have the objective of carrying on the business
of the Partnership for profit and dividing the gain therefrom. 
 12. No election will be made under the Regulations for the
Partnership to be treated as a corporation. 
 Our opinions are also subject to all the assumptions, qualifications, and
limitations set forth in the following discussion, including the assumptions that each of the Partners has full power, authority, and legal right to enter into and perform his or her obligations under the terms of the Partnership Agreement and to
take any and all actions thereunder in connection with the transactions contemplated thereby. 
 Each prospective investor
should be aware that, unlike a ruling from the Service, an opinion of counsel represents only such counsel’s best judgment. THERE CAN BE NO ASSURANCE THAT THE SERVICE WILL NOT SUCCESSFULLY ASSERT POSITIONS WHICH ARE INCONSISTENT WITH OUR
OPINIONS SET FORTH IN THIS DISCUSSION OR IN THE TAX REPORTING POSITIONS TAKEN BY THE PARTNERS OR THE PARTNERSHIP. EACH PROSPECTIVE INVESTOR SHOULD CONSULT HIS OWN TAX ADVISOR TO DETERMINE THE EFFECT OF THE TAX ISSUES DISCUSSED HEREIN ON HIS
INDIVIDUAL TAX SITUATION. 
 PARTNERSHIP STATUS 

The Partnership will be formed as a limited partnership pursuant to the Partnership Agreement and the laws of the State of Oklahoma. The
characterization of the Partnership as a partnership by state or local law, however, will not be determinative of the status of the Partnership for federal income tax purposes. The availability of any federal income tax benefits to an investor is
dependent upon classification of the Partnership as a partnership rather than as a corporation or as an association taxable as a corporation for federal income tax purposes. 
 We are of the opinion that the Partnership will be treated as a partnership for federal income tax purposes, and not as a corporation, an association taxable as a corporation or a “publicly traded
partnership.” However, there can be no assurance that the Service will not attempt to treat the Partnership as a corporation or as an association taxable as a corporation for federal income tax purposes. If the Service were to prevail on this
issue, the tax benefits associated with taxation as a partnership would not be available to the Partners. 
 Although the
Partnership will be validly organized as a limited partnership under the laws of the state of Oklahoma and will be subject to the Act, whether it will be treated for federal income tax purposes as a partnership or as a corporation or as an
association taxable as a corporation will be determined under the Code rather than local law. As discussed below, our opinion that the Partnership will not be classified a corporation or as an association taxable as a corporation is based in part on
entity classification Regulations and in part on the fact that in our opinion the Partnership will not constitute a “publicly traded partnership.” 








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	A.	Association Taxable as a Corporation 

 Our opinion that the Partnership will not be treated as an association taxable as a corporation is based on Regulations issued by the Internal Revenue Service regarding the tax classification of certain
business organizations (the “Check the Box Regulations”). 
 Under the Check the Box Regulations, in general, a
business entity that is not otherwise required to be treated as a corporation under such Regulations will be classified as a partnership if it has two or more members, unless the business entity elects to be treated as a corporation. The Partnership
is not required under the Check the Box Regulations to be treated as a corporation and the General Partner has represented that it will not elect that the Partnership be treated as a corporation. Accordingly, in our opinion the Partnership will not
be treated as an association taxable as a corporation. 
  

	B.	Publicly Traded Partnerships 

 Under Code Section 7704 certain “publicly traded partnerships” (“PTPs”) are treated as corporations for federal income tax purposes. Congress defined a PTP as any partnership,
interests in which are either traded on an established securities market or readily tradable on a secondary market (or the substantial equivalent thereof). Code Section 7704(b). Regulation Section 1.7704-1(b) provides that an
“established securities market” includes a national securities exchange registered under Section 6 of the Securities Exchange Act of 1934 (the “1934 Act”), a national securities exchange exempt under the 1934 Act because of
the limited volume of transactions, certain foreign security laws, regional or local exchanges, and an interdealer quotation system that regularly disseminates firm buy or sell quotations by identified brokers or dealers. The General Partner has
represented that the Units will not be traded on an established securities market. 
 Notwithstanding the above general
treatment of PTPs, Code Section 7704(c) creates an exception to the treatment of PTPs as corporations for any taxable year if 90% or more of the gross income of the partnership for such taxable year consists of “qualifying income.”
Code Section 7704(c)(2). For this purpose, qualifying income is defined to include, inter alia, “income and gains derived from the exploration, development, mining or production, processing, refining... or the marketing of any
mineral or natural resource...” Code Section 7704(d)(1)(E). The General Partner has represented that for all taxable years of the Partnership, 90% or more of the Partnership’s gross income will consist of such qualifying income.

 Legislative history provides that PTPs include entities with respect to which, inter alia, (i) “the holder
of an interest has a readily available, regular and ongoing opportunity to sell or exchange his interest through a public means of obtaining or providing information of offers to 








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buy, sell or exchange interests,” (ii) “prospective buyers and sellers have the opportunity to buy, sell or exchange interests in a time frame and with the regularity and
continuity that the existence of a market maker would provide,” and (iii) there exists a “regular plan of redemptions or repurchases” or similar acquisitions of interests in the partnership such that holders of interests have
readily available, regular and ongoing opportunities to dispose of their interests.” 
 The Service issued Regulation
Section 1.7704-1 to clarify when partnership interests that are not traded on an established securities market will be treated as readily tradable on a secondary market or the substantial equivalent thereof. Essentially, the Regulation provides
that such a situation occurs if partners are readily able to buy, sell, or exchange their partnership interests in a manner that is comparable, economically, to trading on an established securities market. In addition, Notice 88-76 and the
Regulation provide limited safe harbors from the definition of a PTP in advance of the issuance of final Regulations. It is unclear whether the limited safe harbors provided in the Notice and Regulation would result in the Units being treated as not
publicly traded and we express no opinion regarding this matter. However, the General Partner’s obligation to purchase Units pursuant to the right or presentment described in the Memorandum is conditioned upon the receipt by the Partnership
from its counsel of an opinion that such offers or obligations to offer will not cause the Partnership to be treated as “publicly traded.” 
 The Partnership, in our opinion, will not be treated as a PTP prior to any purchases of Units pursuant to the right of presentment. Accordingly, the Partnership, in our opinion, will not be treated as a
corporation for federal income tax purposes under Code Section 7704 in the absence of the Partnership’s interests being “readily tradable on a secondary market (or the substantial equivalent thereof).” 

Notwithstanding the above, the Service may promulgate Regulations or release announcements which take the position that interests in
partnerships such as the Partnership are readily tradable on a secondary market or the substantial equivalent thereof. However, treatment of the Partnership as a PTP should not result in its treatment as a corporation for federal income tax purposes
due to the exception contained in Code Section 7704(c) relating to PTPs meeting the 90% of gross income test so long as such gross income test is satisfied. 
  

	C.	Summary 

 Based on the
above, in our opinion the Partnership will not be treated as an association taxable as corporation for federal income tax purposes by reason of the Check the Box Regulations. Further, since any obligation of the General Partner to purchase Units is
conditioned upon the receipt of an opinion of counsel that the Partnership will not be treated as a PTP, and assuming the Partnership satisfies the 90% gross income test of Code Section 7704, the Partnership, in our opinion, will not be treated
as a corporation for federal income tax purposes. Accordingly, the Partnership in our opinion will be treated as partnership for federal income tax purposes. If challenged by the Service on this issue, the Partners should prevail on the merits, and
each Partner should be entitled to report his proportionate share of the Partnership’s items of income and deductions on his individual federal income tax return. 








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 If in any taxable year the Partnership were to be treated for federal income tax
purposes as a corporation or as an association taxable as a corporation, the Partnership income, gain, loss, deductions, and credits would be reflected only on its “corporate” tax return rather than being passed though to the Partners. In
such event, the Partnership would be required to pay income tax at corporate rates on its net income, thereby reducing the amount of cash available to be distributed to the Partners. Additionally, all or a portion of any distribution made to
Partners would be taxable as dividends, which would not be deductible by the Partnership and which would generally be treated as ordinary portfolio income to the Partners, regardless of the source from which such distributions were generated.

 The discussion that follows is based on the assumption that the Partnership will be classified as a partnership for federal
income tax purposes. 
 FEDERAL TAXATION OF THE PARTNERSHIP 

Under the Code, a partnership is not a taxable entity and, accordingly, incurs no federal income tax liability. Rather, a partnership is
a “pass-through” entity which is required to file an information return with the Service. In general the character of a partner’s share of each item of income, gain, loss, deduction, and credit is determined at the partnership level.
Each partner is allocated a distributive share of such items in accordance with the partnership agreement and is required to take such items into account in determining the partner’s income. Each partner includes such amounts in income for any
taxable year of the partnership ending within or with the taxable year of the partner, without regard to whether the partner has received or will receive any cash distributions from the Partnership. 

A partnership anti-abuse Regulation promulgated under Reg. Section 1.701-2 authorizes the Service to recharacterize a partnership
transaction if (1) a partnership is formed or availed of in connection with a transaction a principal purpose of which is to reduce substantially the present value of the partners’ aggregate federal income tax liability, and
(2) the transaction is inconsistent with the intent of the Subchapter K partnership provisions. Additionally, the Regulation permits the Service to treat a partnership as an aggregate of its partners, in whole or in part, as appropriate,
to carry out the purpose of any provision of the Code or the Regulations. The scope of this Regulation is unclear at this time. Accordingly, we are unable to express an opinion as to its effect, if any, on the Partnership. 








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 OWNERSHIP OF PARTNERSHIP PROPERTIES 

The General Partner has indicated that it, as nominee for the Partnership (the “Nominee”), will acquire and hold title to
Partnership Properties on behalf of the Partnership. The Nominee and the Partnership will enter into an agency agreement before the Nominee acquires any oil and gas properties on behalf of the Partnership. That agency agreement will reflect that the
Nominee's acquisition of Partnership Properties is on behalf of the Partnership. For various cost and procedural reasons, the assignments of all oil and gas interests acquired by the Nominee on behalf of the Partnership to the Partnership will not
be recorded in the real estate records in the counties in which the Partnership Properties are located. That is, while the Partnership will be the owner of the Partnership Properties, there will be no public record of that ownership. It is possible
that the Service could assert that the Nominee should be treated for federal income tax purposes as the owner of the Partnership Properties, notwithstanding the assignment of those Partnership Properties to the Partnership. If the Service were to
argue successfully that the Nominee should be treated as the tax owner of the Partnership Properties, there would be significant adverse federal income tax consequences to the Limited Partners, such as the unavailability of depletion deductions in
respect of income from Partnership Properties. The Service is concerned that taxpayers not be able to shift the tax consequences of transactions between parties based on the parties’ declaration that one party is the agent of another; the
Service generally requires that taxpayers respect the form of their transactions and ownership of property. Based on this concern, the Service may challenge the Partnership’s treatment of Partnership Properties, and tax attributes thereof,
which are held of record by the Nominee. 
 In Commissioner of Internal Revenue v. Bollinger, 485 U.S. 340 (1988),
the United States Supreme Court reviewed a principal-agent relationship and held for the taxpayer in concluding that the principal should be treated as the tax owner of property held in the name of the agent. In that case the Supreme Court noted
that “It seems to us that the genuineness of the agency relationship is adequately assured, and tax-avoiding manipulation adequately avoided, when the fact that the corporation is acting as agent for its shareholders with respect to a
particular asset is set forth in a written agreement at the time the asset is acquired, the corporation functions as agent and not principal with respect to the asset for all purposes, and the corporation is held out as the agent and not principal
in all dealings with third parties relating to the asset.” While the Partnership and the Nominee will have in place an agreement defining their relationship before any Partnership Properties are acquired by the Nominee and the Nominee will
function as agent with respect to those Partnership Properties on behalf of the Partnership, the Nominee will not hold itself out to all third parties as the agent of the Partnership in dealings relating to the Partnership Properties. Unlike the
relationship between the principal and the agent in Bollinger, the Nominee will, however, assign title to Partnership Properties to the Partnership, but will not record those assignments. Accordingly, the facts related to the relationship
between the Nominee and the Partnership are not the same as the facts in Bollinger and it is not clear that the failure of the Nominee to hold itself out to third parties as the agent of the Partnership in dealings relating to Partnership
Properties would result in the treatment of the Nominee as the tax owner of the Partnership Properties. For the foregoing reasons, we have not expressed an opinion on 








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this issue, but we believe that substantial arguments may be made that the Partnership should be treated as the tax owner of Partnership Properties acquired by the Nominee on the
Partnership’s behalf. If the Partnership were not treated as the tax owner of the Partnership Properties, then our conclusions with respect to the following discussions which relate to the Partners’ deduction of tax items which are derived
from Partnership Properties, such as IDC, depletion and Depreciation, would not be applicable. 
 INTANGIBLE DRILLING AND
DEVELOPMENT COSTS DEDUCTIONS 
 Under Code Section 263(a), taxpayers are denied deductions for capital expenditures,
which expenditures are those that generally result in the creation of an asset having a useful life which extends substantially beyond the close of the taxable year. See also Treas. Reg. Section 1.461-1(a)(2). In Indopco, Inc. v.
Commissioner, 92-1 USTC paragraph 50,113 (1992), the Supreme Court seemed to further limit the capitalization criteria by stating that the costs should be capitalized when they provide benefits that extend beyond one tax year.
Notwithstanding these statutory and judicial general rules, Congress has granted to the Secretary of the Treasury the authority to prescribe Regulations that would allow taxpayers the option of deducting, rather than capitalizing, intangible
drilling and development costs (“IDC”). Code Section 263. The Secretary’s rules are embodied in Treas. Reg. Section 1.612-4 and state that, in general, the option to deduct IDC applies only to expenditures for drilling and
development items that do not have a salvage value. 
 With respect to IDC incurred by a partnership, Code Section 703 and
Treas. Reg. Section 1.703-1(b) provide that the option to deduct such costs is to be exercised at the partnership level and in the year in which the deduction is to be taken. All partners are bound by the partnership’s election. The
General Partner has represented that the Partnership will elect to deduct IDC in accordance with Treas. Reg. Section 1.612-4. In this regard, subject to such provision, Limited Partners will be entitled to deduct IDC against passive income in
the year in which the investment is made, provided wells are spudded within the first ninety days of the following year. 
  

	A.	Classification of Costs 


In general, IDC consists of those costs which in and of themselves have no salvage value. Treas. Reg. Section 1.612-4(a) provides
examples of items to which the option to deduct IDC applies, including all amounts paid for labor, fuel, repairs, hauling, and supplies, or any of them, which are used (i) in the drilling, shooting, and cleaning of wells, (ii) in such
clearing of ground, draining, road making, surveying, and geological works as are necessary in the preparation for the drilling of wells, and (iii) in the construction of such derricks, tanks, pipelines, and other physical structures as are
necessary for the drilling of wells and the preparation of wells for the production of oil or gas. The Service, in Rev. Rul. 70-414, 1970-2 C.B. 132, set forth further classifications of items subject to the option and those considered
capital in nature. The ruling provides that the following items are not subject to the election of Treas. Reg. 








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Section 1.612-4(a): (i) oil well pumps (upon initial completion of the well), including the necessary housing structures; (ii) oil well pumps (after the well has flowed for a
time), including the necessary housing structures; (iii) oil well separators, including the necessary housing structures; (iv) pipelines from the wellhead to oil storage tanks on the producing lease; (v) oil storage tanks on the
producing lease; (vi) salt water disposal equipment, including any necessary pipelines; (vii) pipelines from the mouth of a gas well to the first point of control, such as a common carrier pipeline, natural gasoline plant, or carbon black
plant; (viii) recycling equipment, including any necessary pipelines; and (ix) pipelines from oil storage tanks on the producing leasehold to a common carrier pipeline. 

A partnership’s classification of a cost as IDC is not binding on the government, which might reclassify an item labeled as IDC as a
cost which must be capitalized. In Bernuth v. Commissioner, 57 T.C. 225 (1971), aff’d, 470 F.2d 710 (2nd Cir. 1972), the Tax Court denied taxpayers a deduction for that portion of a turnkey drilling contract price that was in
excess of a reasonable cost for drilling the wells in question under a turnkey contract, holding that the amount specified in the turnkey contract was not controlling. Similarly, the Service, in Rev. Rul. 73-211, 1973-1 C.B. 303, concluded that
excessive turnkey costs are not deductible as IDC: 
 [o]nly that portion of the amount of the taxpayer’s total investment
that is attributable to intangible drilling and development costs that would have been incurred in an arm’s-length transaction with an unrelated drilling contractor (in accordance with the economic realities of the transaction) is deductible
[as IDC]. 
 To the extent the Partnership’s prices meet the reasonable price standards imposed by Bernuth,
supra, and Rev. Rul 73-211, supra, and to the extent such amounts are not allocable to tangible property, leasehold costs, and the like, the amounts paid to the General Partner or its affiliates under drilling contracts should
qualify as IDC and should be deductible at the time described below under “B. Timing of Deductions”. That portion of the amount paid to the General Partner or its affiliates that is in excess of the amount that would be charged by an
independent driller under similar conditions will not qualify as IDC and will be required to be capitalized. 
 We are unable to
express an opinion regarding the reasonableness or proper characterization of the payments under the drilling contracts, since the determination of whether the amounts are reasonable or excessive is inherently factual in nature. No assurance can be
given that the Service will not characterize a portion of the amount paid to the General Partner or its affiliates as an excessive payment, to be capitalized as a leasehold cost, assignment fee, syndication fee, organization fee, or other cost, and
not deductible as IDC. To the extent not deductible such amounts will be included in the Partners’ bases in their interests in the Partnership. 








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	B.	Timing of Deductions 

 As
described above, Code Section 263(c) and Treas. Reg. Section 1.612-4 allow the Partnership to expense IDC as opposed to capitalizing such amounts. Even if the Partnership elects to expense the IDC, assuming a taxpayer is otherwise entitled
to such a deduction, the taxpayer may elect to capitalize all or a part of the IDC and amortize the same on a straight-line basis over a sixty month period, beginning with the taxable month in which such expenditure is made. Code
Section 59(e)(1) and (2)(c). 
 For taxpayers entitled to deduct IDC, the timing of such deduction can vary, depending, in
part, upon the taxpayer’s method of accounting. The General Partner has represented that the Partnership will use the accrual method of accounting. Under the accrual method, income is recognized when all the events have occurred which fix the
right to receive such income and the amount thereof can be determined with reasonable accuracy. Reg. Section 1.451-1(a). With respect to deductions, recognition results when all events which establish liability have occurred and the amount
thereof can be determined with reasonable accuracy. Reg. Section 1.461-1(a)(2). Regarding deductions, Code Section 461(h)(1) provides that “. . . the all events test shall not be treated as met any earlier than when economic
performance with respect to such item occurs.” 
 Code Section 461(i)(2), provides that, in the case of a “tax
shelter,” economic performance with respect to the act of drilling an oil or gas well will “. . . be treated as having occurred within a taxable year if drilling of the well commences before the close of the 90th day after the
close of the taxable year.” The Code Section 461 definition of a “tax shelter” is expansive and would include the Partnership. However, with respect to a tax shelter which is a partnership, the maximum deduction that would be
allowable for any prepaid expenses under this exception would be limited to the partner’s “cash basis” in the partnership. Code Section 461(i)(2)(B)(i). Such “cash basis equals the partner’s adjusted basis in the
partnership, determined without regard to (i) any liability of the partnership and (ii) any amount borrowed by the partner with respect to the partnership which (I) was arranged by the partnership or by any person who participated in
the organization, sale, or management of the partnership (or any person related to such person within the meaning of Code Section 465(b)(3)(C)) or (II) was secured by any assets of the partnership”. Code Section 461(i)(2)(C). The
General Partner has represented that drilling operations for Partnership wells will commence by the spudding of each well on or before December 31, 2010. If completion is warranted, each well will be completed with due diligence thereafter.
Further the General Partner has represented that, in any event, the Partnership will not have any such liability referred to in Code Section 461(i)(2)(C), and the Partners will not so incur any such debt so as to result in application of the
limiting provisions contained in Code Section 461(i)(2)(B)(i). 
 Notwithstanding the above, the deductibility of any
prepaid IDC will be subject to the limitations of case law. These limitations provide that prepaid IDC is deductible when paid if (i) the expenditure constitutes a payment that is not merely a deposit, (ii) the payment is made for a
business purpose, and (iii) deductions attributable to such outlay do not result in a material 








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distortion of income. See Keller v. Commissioner, 79 T.C. 7 (1982), aff’d, 725 F.2d 1173 (8th Cir. 1984), Rev. Rul. 71-252, 1971-1 C.B. 146, Pauley v.
U.S., 63-1 U.S.T.C. paragraph 9280 (S.D. Cal. 1963), Rev. Rul. 80-71, 1980-1 C.B. 106, Jolley v. Commissioner, 47 T.C.M. 1082 (1984), Dillingham v. U.S., 81-2 U.S.T.C. paragraph 9601 (W.D. Okla. 1981), and
Stradlings Building Materials, Inc. v. Commissioner, 76 T.C. 84 (1981). Generally, these requirements may be met by a showing of a legally binding obligation (i.e., the payment was not merely a deposit), of a legitimate business purpose
for the payment, that performance of the services was required within a reasonable time, and of an arm’s-length price. Similar requirements apply to cash basis taxpayers seeking to deduct prepaid IDC. 

The General Partner is unable to represent that all of the Partnership’s wells will be completed in 2011; however, the General
Partner has represented that any such well that is not completed in 2011 will be spudded by not later than December 31, 2011. 
 The Service has challenged the timing of the deduction of IDC when the wells giving rise to such deduction have been completed in a year subsequent to the year of prepayment. The decisions noted above
hold that prepayments of IDC by a cash basis taxpayer are, under certain circumstances, deductible in the year of prepayment if some work is performed in the year of prepayment even though the well is not completed that year. 

In Keller v. Commissioner, supra, the Eighth Circuit Court of Appeals applied a three-part test for determining the current
deductibility of prepaid IDC by a cash basis taxpayer, namely whether (i) the expenditure was a payment or a mere deposit, (ii) the payment was made for a valid business purpose and (iii) the prepayment resulted in a material
distortion of income. The facts in that case dealt with two different forms of drilling contracts: footage or day-work contracts and turnkey contracts. Under the turnkey contracts, the prepayments were not refundable in any event, but in the event
work was stopped on one well the remaining unused amount would be applied to another well to be drilled on a turnkey basis. Contrary to the Service’s argument that this substitution feature rendered the payment a mere deposit, the court in
Keller concluded that the prepayments were indeed “payments” because the taxpayer could not compel a refund. The court further found that the deduction clearly reflected income because under the unique characteristics of the turnkey
contract the taxpayer locked in the price and shifted the drilling risk to the contractor, for a premium, effectively getting its bargained for benefit in the year of payment. Therefore, the court concluded that the cash basis taxpayers in that case
properly could deduct turnkey payments in the year of payment. With respect to the prepayments under the footage or day-work contracts, however, the court found that the payments were mere deposits on the facts of the case, because the partnership
had the power to compel a refund. The court was also unconvinced as to the business purpose for prepayment under the footage or day-work contracts, primarily because the testimony indicated that the drillers would have provided the required services
with or without prepayment. 








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 Under the terms of drilling and operating agreements to be entered into by and between
the Partnership and the General Partners or its affiliates, if amounts paid by the Partnership prior to the commencement of drilling exceed amounts due the General Partner or its affiliates thereunder, the General Partner or its affiliates will not
refund any portion of amounts paid by the Partnership, but rather will create a credit once the actual costs incurred by the General Partner or its affiliates are compared to the amounts paid. 

The Service has adopted the position that the relationship between the parties may provide evidence that the drilling contract between
the parties requiring prepayment may not be a bona fide arm’s-length transaction, in which case a portion of the prepayment may be disallowed as being a “non-required payment.” The Service has formally applied its position on
prepayments to related parties in Revenue Ruling 80-71. 1980-1 C.B. 106. In this ruling, a subsidiary corporation, which was a general partner in an oil and gas limited partnership, prepaid the partnership’s drilling and completion costs
under a turnkey contract entered into with the corporate parent of the general partner. The agreement did not provide for any date for commencing drilling operations and the contractor, which did not own any drilling equipment, was to arrange for
the drilling equipment for the wells through subcontractors. Revenue Ruling 71-252, supra, was factually distinguished on the grounds of the business purpose of the transaction, immediate expenditure of prepaid receipts, and completion
of the wells within two and one-half months. Rev. Rul. 80-71 found that the prepayment was not made in accordance with customary business practice and held on the facts that the payment was deductible in the tax year that the related general
contractor paid the independent subcontractor. 
 However, in Tom B. Dillingham v. United States, 1981-2 USTC
paragraph 9601 (D.C. Okla. 1981), the court held that, on the facts before it, a contract between related parties requiring a prepaid IDC did give rise to a deduction in the year paid. In that case, Basin Petroleum Corp. (“Basin”) was
the general partner of several drilling partnerships and also served as the partnership operator and general contractor. As general contractor, Basin was to conduct the drilling of the wells at a fixed price on a turnkey basis under an agreement
that required payment prior to the end of the year in question. The stated reason for the prepayment was to provide Basin with working capital for the drilling of the wells and to temporarily provide funds to Basin for other operations. The
agreement required drilling to commence within a reasonable period of time, and all wells were completed within the following year. Some of the wells were drilled by Basin with its own rigs and some were drilled by subcontractors. The court stated:

 The fact that the owner and contractor is the general partner of the partnership-owner does not change this result where, as
here, the Plaintiffs have shown that prepayment was required for a legitimate business purpose and the transaction was not a sham to merely permit Plaintiff to control the timing of the deduction. IRC, Sec. 707(a). Plaintiffs were entitled to
rely upon Revenue Ruling 71-252 by reason of Income Tax Regulations 26 C.F.R. Section 601.601(d)(2)(v)(e) . . . 

Notwithstanding the foregoing, no assurance can be given that the Service will not challenge the current deduction of IDC because of the prepayment being
made to a related party. If the Service were successful with such challenge, the Partners’ deductions for IDC would be deferred to later years. 








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 The timing of the deductibility of prepaid IDC is inherently a factual determination
which is to a large extent predicated on future events. The General Partner has represented that the drilling and operating agreements to be entered into with an affiliate of the General Partner by the Partnership will be duly executed by and
delivered to such affiliate, the Partnership and the General Partner as attorney-in-fact for the Partners and will govern the drilling, and, if warranted, the completion of each of the Partnership’s wells. Based upon this representation and
others included within the opinion and assuming that the drilling and operating agreements will be performed in accordance with their terms, we are of the opinion that the payment for IDC under the drilling and operating agreements, if made in 2011,
will be allowable as a deduction in 2011, subject to the other limitations discussed in this opinion. Although the General Partner will attempt to satisfy each requirement of the Service and judicial authority for deductibility of IDC in 2011, no
assurance can be given that the Service will not successfully contend that the IDC of a well which is not completed until 2012 are not deductible in whole or in part until 2012. 

 

	C.	Recapture of IDC 

 IDC
which has been deducted is subject to recapture as ordinary income upon certain dispositions (other than by abandonment, gift, death, or tax-free exchange) of an interest in an oil or gas property. IDC previously deducted that is allocable to the
property (directly or through the ownership of an interest in a partnership) and which would have been included in the adjusted basis of the property is recaptured to the extent of any gain realized upon the disposition of the property. Regulations
provide that recapture is determined at the partner level (subject to certain anti-abuse provisions). Reg. Section 1.1254-5(b). Where only a portion of recapture property is disposed of, any IDC related to the entire property is recaptured to
the extent of the gain realized on the portion of the property sold. In the case of the disposition of an undivided interest in a property (as opposed to the disposition of a portion of the property), a proportionate part of the IDC with respect to
the property is treated as allocable to the transferred undivided interest to the extent of any realized gain. Reg. Section 1.1254-1(c). 








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 DEPLETION DEDUCTIONS 

The owner of an economic interest in an oil and gas property is entitled to claim the greater of percentage depletion or cost depletion
with respect to oil and gas properties which qualify for such depletion methods. In the case of partnerships, the depletion allowance must be computed separately by each partner and not by the partnership. Code Section 613A(c)(7)(D).
Notwithstanding this requirement, however, the Partnership, pursuant to Section 3.01(d)(i) of the Partnership Agreement, will compute a “simulated depletion allowance” at the Partnership level, solely for the purposes of maintaining
Capital Accounts. Code Sections 613A(d)(2) and 613A(d)(4). 
 Cost depletion for any year is determined by multiplying the
number of units (e.g., barrels of oil or Mcf of gas) sold during the year by a fraction, the numerator of which is the cost of the mineral interest and the denominator of which is the estimated recoverable units of reserve available as of the
beginning of the depletion period. See Treas. Reg. Section 1.611-2(a). In no event can the cost depletion exceed the adjusted basis of the property to which it relates. 
 Percentage depletion is generally available only with respect to the domestic oil and gas production of certain “independent producers.” In order to qualify as an independent producer, the
taxpayer, either directly or through certain related parties, may not be involved in the refining of more than a daily average of 75,000 barrels of oil (or equivalent of gas) during the taxable year or in the retail marketing of oil and gas products
exceeding $5 million per year in the aggregate. 
 In general, (i) component members of a controlled group of corporations,
(ii) corporations, trusts, or estates under common control by the same or related persons and (iii) members of the same family (an individual, his spouse and minor children) are aggregated and treated as one taxpayer in determining the
quantity of production (barrels of oil or cubic feet of gas per day) qualifying for percentage depletion under the independent producer’s exemption. Code Section 613A(c)(8). No aggregation is required among partners or between a partner
and a partnership. An individual taxpayer is related to an entity engaged in refining or retail marketing if he owns 5% or more of such entity. Code Section 613A(d)(3). 
 Percentage depletion is a statutory allowance pursuant to which, under current law, a minimum deduction equal to 15% of the taxpayer’s gross income from the property is allowed in any taxable year,
not to exceed (i) 100% of the taxpayer’s taxable income from the property (computed without the allowance for depletion) or (ii) 65% of the taxpayer’s taxable income for the year (computed without regard to percentage depletion
and net operating loss and capital loss carrybacks). Code Sections 613(a) and 613A(d)(1). The rate of the percentage depletion deduction will vary with the price of oil. In the case of production from marginal properties, the percentage
depletion rate may be increased. Section 613A(c)(6). For purposes of computing the percentage depletion deduction, “gross income from the property” does not include any lease bonus, advance royalty, or other amount payable without
regard to production from the property. 








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Code Section 613A(d)(5). Depletion deductions reduce the taxpayer’s adjusted basis in the property. However, unlike cost depletion, deductions under percentage depletion are not limited
to the adjusted basis of the property; the percentage depletion amount continues to be allowable as a deduction after the adjusted basis has been reduced to zero. 
 Percentage depletion will be available, if at all, only to the extent that a taxpayer’s average daily production of domestic crude oil or domestic natural gas does not exceed the taxpayer’s
depletable oil quantity or depletable natural gas quantity, respectively. Generally, the taxpayer’s depletable oil quantity equals 1,000 barrels and depletable natural gas quantity equals 6,000,000 cubic feet. Code Section 613A(c)(3) and
(4). In computing his individual limitation, a Partner will be required to aggregate his share of the Partnership’s oil and gas production with his share of production from all other oil and gas investments. Code Section 613A(c). Taxpayers
who have both oil and gas production may allocate the deduction limitation between the two types of production. 
 The
availability of depletion, whether cost or percentage, will be determined separately by each Partner. Each Partner must separately keep records of his share of the adjusted basis in an oil or gas property, adjust such share of the adjusted basis for
any depletion taken on such property, and use such adjusted basis each year in the computation of his cost depletion or in the computation of his gain or loss on the disposition of such property. These requirements may place an administrative burden
on a Partner. For properties placed in service after 1986, depletion deductions, to the extent they reduce the basis of an oil and gas property, are subject to recapture under Section 1254. 

SINCE THE AVAILABILITY OF PERCENTAGE DEPLETION FOR A PARTNER IS DEPENDENT UPON THE STATUS OF THE PARTNER AS AN INDEPENDENT PRODUCER,
WE ARE UNABLE TO RENDER ANY OPINION AS TO THE AVAILABILITY OF PERCENTAGE DEPLETION. EACH PROSPECTIVE INVESTOR IS URGED TO CONSULT WITH HIS PERSONAL TAX ADVISOR TO DETERMINE WHETHER PERCENTAGE DEPLETION WOULD BE AVAILABLE TO HIM. 








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 DEPRECIATION DEDUCTIONS 

The Partnership will claim depreciation, cost recovery, and amortization deductions with respect to its basis in Partnership Property as
permitted by the Code. For most tangible personal property, the “modified accelerated cost recovery system” (“MACRS”) must be used in calculating the cost recovery deductions. Thus, the cost of lease equipment and well equipment,
such as casing, tubing, tanks, and pumping units, and the cost of oil or gas pipelines cannot be deducted currently but must be capitalized and recovered under “MACRS.” The cost recovery deduction for most equipment used in domestic oil
and gas exploration and production and for most of the tangible personal property used in natural gas gathering systems is calculated using the 200% declining balance method switching to the straight-line method, a seven-year recovery period, and a
half-year convention. 
 INTEREST DEDUCTIONS 
 In the Transaction, the Limited Partners will acquire their interests by remitting cash in the amount of $1,000 per Unit to the Partnership (employees of Unit Corporation and its subsidiaries may elect
payroll withholding). In no event will the Partnership accept notes in exchange for a Partnership interest. Nevertheless, without any assistance of the General Partner or any of its affiliates, some Partners may choose to borrow the funds necessary
to acquire a Unit and may incur interest expense in connection with those loans. Based upon the purely factual nature of any such loans, we are unable to express an opinion with respect to the deductibility of any interest paid or incurred thereon.

 TRANSACTION FEES 
 The Partnership may classify a portion of the fees or expense reimbursement payments (the “Fees”) to be paid to third parties and to the General Partner or its affiliates as expenses which are
deductible as organizational expenses or otherwise. There is no assurance that the Service will allow the deductibility of such expenses and we express no opinion with respect to the allocation of the Fees to deductible and nondeductible items.

 Generally, expenditures made in connection with the creation of, and with sales of interests in, a partnership will fit
within one of several categories. 
 For the taxable year in which it begins business the Partnership may elect to deduct its
organizational expenses (as defined in Code Section 709(b)(2) and in Reg. Section 1.709-2(a)) in an amount equal to the lesser of (i) the amount of the organizational expenses, or (ii) $5,000, reduced (but not below zero) by the
amount by which such organizational expenses exceed $50,000. The remainder of the Partnership’s organizational expenses will be allowable as a deduction ratably over the 180-month period beginning with the month in which the Partnership begins
business. Organizational expenses are expenses which (i) are incident to the creation of the partnership, (ii) are chargeable to capital account, and (iii) are of a character which, if









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expended incident to the creation of a partnership having an ascertainable life, would (but for Code Section 709(a)) be amortized over such life. Id. Examples of organizational
expenses are legal fees for services incident to the organization of the partnership, such as negotiation and preparation of a partnership agreement, accounting fees for services incident to the organization of the partnership, and filing fees. Reg.
Section 1.709-2(a). 
 Under Code Section 709, no deduction is allowable for “syndication expenses,”
examples of which include brokerage fees, registration fees, legal fees of the underwriter or placement agent and the issuer (general partners or the partnership) for securities advice and for advice pertaining to the adequacy of tax disclosures in
the Memorandum or private placement memorandum for securities law purposes, printing costs, and other selling or promotional material. These costs must be capitalized. Reg. Section 1.709-2(b). Payments for services performed in connection with
the acquisition of capital assets must be amortized over the useful life of such assets. Code Section 263. 
 Under Code
Section 195, for the taxable year in which a taxpayer’s active trade or business begins, the taxpayer may elect to deduct its start-up expenditures in an amount equal to the lesser of (i) the amount of the start-up expenditures, or
(ii) $5,000, reduced (but not below zero) by the amount by which such start-up expenditures exceed $50,000. The remainder of the taxpayer’s start-up expenditures will be allowable as a deduction ratably over the 180-month period beginning
with the month in which the active trade or business begins. Start-up expenditures are defined as amounts (i) paid or incurred in connection with (A) investigating the creation or acquisition of an active trade or business,
(B) creating an active trade or business, or (C) any activity engaged in for profit and for the production of income before the day on which the active trade or business begins, in anticipation of such activity becoming an active trade or
business, and (ii) which, if paid or incurred in connection with the operation of an existing active trade or business (in the same field as the trade or business referred to in (i) above), would be allowable as a deduction for the taxable
year in which paid or incurred. Code Section 195(c)(1). 
 The Partnership intends to make expense reimbursement payments
to the General Partner, as described in the Memorandum. To be deductible, compensation paid to a general partner must be for services rendered by the partner other than in his capacity as a partner or for compensation determined without regard to
partnership income. Fees which are not deductible because they fail to meet this test may be treated as special allocations of income to the recipient partner (see Pratt v. Commissioner, 550 F.2d 1023 (5th Cir. 1977)), and thereby
decrease the net loss or increase the net income among all partners. 
 To the extent these expenditures described in the
Memorandum are considered syndication costs, they will not be deductible by the Partnership. To the extent attributable to organization fees (such as the amounts paid for legal services incident to the organization of the Partnership), the
expenditures may be deducted in part in the Partnership’s first taxable year and the remainder amortizable over a period of 180 months, commencing with the month the Partnership begins business, if the Partnership so elects; if no election
is made, no deduction is 








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available. Finally, to the extent any portion of the expenditures would be treated as “start-up expenditures,” they could be deducted in part in the Partnership’s first taxable
year and the remainder amortizable over a period of 180 months, commencing with the month the Partnership begins business, provided the proper election was made. 
 Due to the inherently factual nature of the proper allocation of expenses among nondeductible syndication expenses, amortizable organization expenses, amortizable “start-up” expenditures, and
currently deductible items, and because the issues involve questions concerning both the nature of the services performed and to be performed and the reasonableness of amounts charged, we are unable to express an opinion regarding such treatment. If
the Service were to successfully challenge the General Partner’s allocations, a Partner’s taxable income could be increased, thereby resulting in increased taxes and in potential liability for interest and penalties. 

BASIS AND AT RISK LIMITATIONS 
 A Partner’s share of Partnership losses will not be allowed as a deduction to the extent such share exceeds the amount of the Partner’s adjusted tax basis in his Units. A Partner’s initial
adjusted tax basis in his Units will generally be equal to the cash he has invested to purchase his Units. Such adjusted tax basis will generally be increased by (i) additional amounts invested in the Partnership, including his share of net
income, (ii) additional capital contributions, if any, and (iii) his share of Partnership borrowings, if any, based on the extent of his economic risk of loss for such borrowings. Such adjusted tax basis will generally be reduced, but not
below zero by (i) his share of loss, (ii) his depletion deductions on his share of oil and gas income (until such deductions exhaust his share of the basis of property subject to depletion), (iii) the amount of cash and the adjusted
basis of property other than cash distributed to him, and (iv) his share of reduction in the amount of indebtedness previously included in his basis. 
 In addition, Code Section 465 provides, in part, that, if an individual or a closely held C (i.e., regularly taxed) corporation engages in any activity to which Code Section 465 applies,
any loss from that activity is allowed only to the extent of the aggregate amount with respect to which the taxpayer is “at risk” for such activity at the close of the taxable year. Code Section 465(a)(1). A closely held
C corporation is a corporation more than fifty percent (50%) of the stock of which is owned, directly or indirectly, at any time during the last half of the taxable year by or for not more than five (5) individuals. Code
Sections 465(a)(1)(B), 542(a)(2). For purposes of Code Section 465, a loss is defined as the excess of otherwise allowable deductions attributable to an activity over the income received or accrued from that activity. Code
Section 465(d). Any such loss disallowed by Code Section 465 shall be treated as a deduction allocable to the activity in the first succeeding taxable year. Code Section 465(a)(2). 

Code Section 465(b)(1) provides that a taxpayer will be considered as being “at risk” for an activity with respect to
amounts including (i) the amount of money and the adjusted basis of other property contributed by the taxpayer to the activity, and (ii) amounts borrowed with respect 








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to such activity to the extent that the taxpayer (A) is personally liable for the repayment of such amounts, or (B) has pledged property, other than property used in the activity, as
security for such borrowed amounts (to the extent of the net fair market value of the taxpayer’s interest in such property). No property can be taken into account as security if such property is directly or indirectly financed by indebtedness
that is secured by property used in the activity. Code Section 465(b)(2). Further, amounts borrowed by the taxpayer shall not be taken into account if such amounts are borrowed (i) from any person who has an interest (other than an
interest as a creditor) in such activity, or (ii) from a related person to a person (other than the taxpayer) having such an interest. Code Section 465(b)(3). 
 Related persons for purposes of Code Section 465(b)(3) are defined to include related persons within the meaning of Code Section 267(b) (which describes relationships between family members,
corporations and shareholders, trusts and their grantors, beneficiaries and fiduciaries, and similar relationships), Code Section 707(b)(1) (which describes relationships between partnerships and their partners) and Code Section 52 (which
describes relationships between persons engaged in businesses under common control). Code Section 465(b)(3)(C). 
 Finally,
no taxpayer is considered at risk with respect to amounts for which the taxpayer is protected against loss through nonrecourse financing, guarantees, stop loss agreements, or other similar arrangements. Code Section 465(b)(4). 

The Code provides that a taxpayer must recognize taxable income to the extent that his “at risk” amount is reduced below zero.
This recaptured income is limited to the sum of the loss deductions previously allowed to the taxpayer, less any amounts previously recaptured. A taxpayer may be allowed a deduction for the recaptured amounts included in his taxable income if and
when he increases his amount “at risk” in a subsequent taxable year. 
 The Treasury has published proposed
Regulations relating to the at risk provisions of Code Section 465. These proposed Regulations provide that a taxpayer’s at risk amount will include “personal funds” contributed by the taxpayer to an activity. Prop. Reg.
Section 1.465-22(a). “Personal funds” and “personal assets” are defined in Prop. Reg. Section 1.465-9(f) as funds and assets which (i) are owned by the taxpayer, (ii) are not acquired through borrowing, and
(iii) have a basis equal to their fair market value. 
 In addition to a taxpayer’s amount at risk being increased by
the amount of personal funds contributed to the activity, the excess of the taxpayer’s share of all items of income received or accrued from an activity during a taxable year over the taxpayer’s share of allowable deductions from the
activity for the year will also increase the amount at risk. Prop. Reg. Section 1.465-22. A taxpayer’s amount at risk will be decreased by (i) the amount of money withdrawn from the activity by or on behalf of the taxpayer, including
distributions from a partnership, and (ii) the amount of loss from the activity allowed as a deduction under Code Section 465(a). Id. 








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 The Partners will purchase Units by tendering cash (or payroll deductions) to the
Partnership. To the extent the cash contributed constitutes the “personal funds” of the Partners, the Partners should be considered at risk with respect to those amounts. To the extent the cash contributed constitutes “personal
funds,” in our opinion, neither the at risk rules nor the adjusted basis rules will limit the deductibility of losses generated from the Partnership. 
 PASSIVE LOSS AND CREDIT LIMITATIONS 
  

	A.	Introduction 

 Code
Section 469 provides that the deductibility of losses generated from passive activities will be limited for certain taxpayers. The passive activity loss limitations apply to individuals, estates, trusts, and personal service corporations as
well as, to a lesser extent, closely held C corporations. Code Section 469(a)(2). 
 The definition of a “passive
activity” generally encompasses all rental activities as well as all activities with respect to which the taxpayer does not “materially participate.” Code Section 469(c). Notwithstanding this general rule, however, the term
“passive activity” does not include “any working interest in any oil or gas property which the taxpayer holds directly or through an entity which does not limit the liability of the taxpayer with respect to such interest.” Code
Section 469(c)(3)(4). 
 A passive activity loss (“PAL”) is defined as the amount (if any) by which the aggregate
losses from all passive activities for the taxable year exceed the aggregate income from all passive activities for such year. Code Section 469(d)(1). 
 Classification of an activity as passive will result in the income and expenses generated therefrom being treated as “passive” except to the extent that any of the income is
“portfolio” income and except as otherwise provided in Regulations. Code Section 469(e)(1)(A). Portfolio income is income from, inter alia, interest, dividends and royalties not derived in the ordinary course of a trade or
business. Income that is neither passive nor portfolio is “net active income.” Code Section 469(e)(2)(B). 
 With
respect to the deductibility of PALs, individuals and personal service corporations will be entitled to deduct such amounts only to the extent of their passive income whereas closely held C corporations (other than personal service corporations) can
offset PALs against both passive and net active income, but not against portfolio income. Code Section 469(a)(1), (e)(2). In calculating passive income and loss, however, all activities of the taxpayer are aggregated. Code
Section 469(d)(1). PALs disallowed as a result of the above rules will be suspended and can be carried forward indefinitely to offset future passive (or passive and active, in the case of a closely held C corporation) income. Code
Section 469(b). 








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 Upon the disposition of an entire interest in a passive activity in a fully taxable
transaction not involving a related party, any passive loss that was suspended by the provisions of the Code Section 469 passive activity rules is deductible from either passive or non-passive income. The deduction must be reduced, however, by
the amount of income or gain realized from the activity in previous years. 
 As noted above, a passive activity includes an
activity with respect to which the taxpayer does not “materially participate.” A taxpayer will be considered as materially participating in a venture only if the taxpayer is involved in the operations of the activity on a “regular,
continuous, and substantial” basis. Code Section 469(h)(1). With respect to the determination as to whether a taxpayer’s participation in an activity is material, temporary Regulations issued by the Service provide that, except for
limited partners in a limited partnership, an individual will be treated as materially participating in an activity if and only if (i) the individual participates in the activity for more than 500 hours during such year, (ii) the
individual’s participation in the activity for the taxable year constitutes substantially all of the participation in such activity of all individuals for such year, (iii) the individual participates in the activity for more than 100 hours
during the taxable year, and such individual’s participation in such activity is not less than the participation in the activity of any other individual for such year, (iv) the activity is a trade or business activity of the individual,
the individual participates in the activity for more than 100 hours during such year, and the individual’s aggregate participation in all significant participation activities of this type during the year exceeds 500 hours, (v) the
individual materially participated in the activity for 5 of the last 10 years, or (vi) the activity is a personal service activity and the individual materially participated in the activity for any 3 preceding years. Temp. Reg.
Section 1.469-5T(a). 
 Notwithstanding the above, and except as may be provided in Regulations, Code
Section 469(h)(2) provides that no limited partnership interest will be treated as an interest with respect to which a taxpayer materially participates. The temporary Regulations create several exceptions to this rule and provide that a limited
partner will not be treated as not materially participating in an activity of the partnership of which he is a limited partner if the limited partner would be treated as materially participating for the taxable year under paragraph (a)(1), (5),
or (6) of Reg. Section 1.469-5T (as described in (i), (v), and (vi) of the above paragraph) if the individual were not a limited partner for such taxable year. Temp. Reg. Section 1.469-5T(e). For purposes of this rule, a
partnership interest of an individual will not be treated as a limited partnership interest for the taxable year if the individual is an Additional General Partner in the partnership at all times during the partnership’s taxable year ending
with or within the individual’s taxable year. Id. 








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	B.	Limited Partner Interests 


If an investor invests in the Partnership as a Limited Partner, in our opinion, his distributive share of the Partnership’s losses
will be treated as PALs, the availability of which will be limited to his passive income thereon. If the Limited Partner does not have sufficient passive income to utilize the PALs, the disallowed PALs will be suspended and may be carried forward
(but not back) to be deducted against passive income arising in future years. Further, upon the complete disposition of the interest to an unrelated party in a fully taxable transaction, such suspended losses will be available, as described above.

 Regarding Partnership income, Limited Partners should generally be entitled to offset their distributive shares of such
income with deductions from other passive activities, except to the extent such Partnership income is portfolio income. Since gross income from interest, dividends, annuities, and royalties not derived in the ordinary course of a trade or business
is not passive income, a Limited Partner’s share of income from royalties, income from the investment of the Partnership’s working capital, and other items of portfolio income will not be treated as passive income. In addition, Code
Section 469(1)(3) grants the Secretary of the Treasury 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. 

 

	C.	Publicly Traded Partnerships 

 Notwithstanding the above, Code Section 469(k) treats net income from PTPs as portfolio income under the PAL rules. Further each partner in a PTP is required to treat any losses from a PTP as
separate from income and loss from any other PTP and also as separate from any income or loss from passive activities. Id. Losses attributable to an interest in a PTP that are not allowed under the passive activity rules are suspended and
carried forward, as described above. Further, upon a complete taxable disposition of an interest in a PTP, any suspended losses are allowed (as described above with respect to the passive loss rules). As noted above, we have opined that the
Partnership will not be a PTP. 
 In the event the Partnership were treated as a PTP, any net income would be treated as
portfolio income and each Partner’s loss therefrom would be treated as separate from income and loss from any other PTP and also as separate from any income or loss from passive activities. Since the Partnership should not be treated as a PTP,
the provisions of Code Section 469(k), in our opinion, will not apply to the Partners in the manner outlined above prior to the time that such Partnership becomes a PTP. However, unlike the PTP rules of Code Section 7704, the passive
activity rules of Code Section 469 do not provide an exception for partnerships that pass the 90% test of Code Section 7704. Accordingly, if the Partnership were to be treated as a PTP under the passive activity rules, passive losses could
be used only to offset passive income from the Partnership. 








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 TAX RATES 

The maximum ordinary income tax rate for individuals is 35% (but such rate is scheduled to increase to 39.6% for
taxable years beginning after December 31, 2012). In general, the maximum individual income tax rate for “Qualified Dividends”[1] and long-term capital gains is 15% (unless the taxpayer elects to be taxed at ordinary rates as provided in the
Code). However, for taxable years beginning after December 31, 2012, generally the maximum individual rates will be 20% for long-term capital gains and 39.6% for dividends. The excess of capital losses over capital gains may be offset
against the ordinary income of an individual taxpayer, subject to an annual deduction limitation of U.S. $3,000. Capital losses of an individual taxpayer may generally be carried forward to succeeding tax years to offset capital gains and then
ordinary income (subject to the U.S. $3,000 annual limitation). For corporate taxpayers, the maximum income tax rate is 35%. Capital losses of a corporate taxpayer may be offset only against capital gains, but unused capital losses may be
carried back three years (subject to certain limitations) and carried forward five years. 
 For taxable years beginning after
December 31, 2012, an individual or estate, or a trust that does not fall into a special class of trusts that is exempt from such tax, will be subject to a 3.8% tax (“Medicare tax”) on the lesser of (1) the taxpayer’s
“net investment income” for the relevant taxable year and (2) the excess of the taxpayer’s modified gross income for the taxable year over a certain threshold (which, in the case of individuals, will be between $125,000 and
$250,000 depending on the individual’s circumstances). A taxpayer’s “net investment income” may generally include, among other items, certain interest, dividends, gain, and other types of income from investments, minus the
allowable deductions that are properly allocable to that gross income or net gain. A prospective investor that is an individual, estate or trust should consult its tax advisor regarding the applicability of the Medicare tax to allocations of income
and gain from the Partnership to a Limited Partner. 
 ALTERNATIVE MINIMUM TAX 

Code Section 55 imposes on noncorporate taxpayers a two-tiered, graduated rate schedule for alternative minimum tax
(“AMT”) equal to the sum of (i) 26% of so much of the “taxable excess” as does not exceed $175,000, plus (ii) 28% of so much of the “taxable excess” as exceeds $175,000 (for married individuals filing
jointly). Code Section 55(b)(1)(A)(i). “Taxable excess” is defined as so much of the alternative minimum taxable income (“AMTI”) for the taxable year as exceeds the exemption amount. Code Section 55(b)(1)(A)(ii). AMTI
is generally defined as the taxpayer’s taxable income, increased or decreased by certain adjustments and items of tax preference. Code Section 55(b)(2). 
  

 

	[1]	A “Qualified Dividend” is generally a dividend from certain domestic corporations, and from certain foreign corporations that are either eligible
for the benefits of a comprehensive income tax treaty with the United States or are readily tradable on an established securities market in the United States. Shares must be held for certain holding periods in order for a dividend thereon to be
a Qualified Dividend. 









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 The 2010 exemption amount for non-corporate taxpayers is (i) $70,950 in the case of
a joint return or a surviving spouse, (ii) $46,700 in the case of an individual who is not a married individual or a surviving spouse, and (iii) $35,475 in the case of a married individual who files a separate return or an estate or trust.
Such amounts are phased out as a taxpayer’s AMTI increases above certain levels. Individuals subject to the AMT are generally allowed a credit, equal to the portion of the AMT imposed by Code Section 55 arising as a result of deferral
preferences for use against the taxpayer’s future regular tax liability (but not the minimum tax liability). 
 Under the
AMT provisions, adjustments and items of tax preference that may arise from a Partner’s acquisition of an interest in the Partnership include the following: 
 1. Taxpayers which do not meet the definition of an integrated oil company as defined in Code Section 291(b)(4) are not subject to the preference item for “excess IDC.” Code
Section 57(a)(2)(E)(i). The benefit of the elimination of the preference is limited in any taxable year to an amount equal to 40 percent of the alternative minimum taxable income for the year computed as if the prior law “excess
IDC” preference item has not been eliminated. Code Section 57(a)(2)(E)(ii). Excess IDC is defined as the excess of (i) IDC paid or incurred (other than costs incurred in drilling a nonproductive well) with respect to which a deduction
is allowable under Code Section 263(c) for the taxable year over (ii) the amount which would have been allowable for the taxable year if such costs had been capitalized and (I) amortized over a 120 month period beginning with the
month in which production from such well begins or (II) recovered through cost depletion. Code Section 57(a)(2)(B). However, any portion of the IDC to which an election under Code Section 59(e) applies will not be treated as an item
of tax preference under Code Section 57(a). Code Section 59(e)(6). With respect to IDC paid or incurred, corporate and individual taxpayers are allowed to make the Code Section 59(e) election and, for regular tax and AMT purposes,
deduct such expenditures over the 60 month period beginning with the month in which such expenditure is paid or incurred. Code Section 59(e)(1). 
 2. The preference item for excess depletion is repealed for other than integrated oil companies. Code Section 57(a)(1). 
 3. Each Partner’s AMTI will be increased (or decreased) by the amount by which the depreciation deductions allowable under Code Sections 167 and 168 with respect to such property exceeds (or is
less than) the depreciation determined under the alternative depreciation system using the one hundred fifty percent (150%) declining balance method switching to the straight-line method, when that produces a greater deduction, in lieu of the
straight-line method otherwise prescribed by the ADS. Code Section 56(a)(1). 
 Due to the inherently factual nature of the
applicability of the AMT to a Partner, we are unable to express an opinion with respect to such issues. Due to the potentially significant impact of a purchase of Units on an investor’s tax liability, investors should discuss the implications
of an investment in the Partnership on their regular and AMT liabilities with their tax advisors prior to acquiring Units. 








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 GAIN OR LOSS ON SALE OF PROPERTIES 

Gain from the sale or other disposition of property is realized to the extent of the excess of the amount realized therefrom over the
property’s adjusted basis; conversely, loss is realized in an amount equal to the excess of the property’s adjusted basis over the amount realized from such a disposition. Code Section 1001(a). The amount realized is defined as the
sum of any money received plus the fair market value of the property (other than money) received. Code Section 1001(b). Accordingly, upon the sale or other disposition of the Partnership properties, the Partners will realize gain or loss to the
extent of their pro rata share of the difference between the Partnership’s adjusted basis in the property at the time of disposition and the amount realized upon disposition. In the absence of nonrecognition provisions, any gain or loss
realized will be recognized for federal income tax purposes. 
 Gain or loss recognized upon the disposition of property used in
a trade or business and held for more than one year will be treated as long term capital gain or as ordinary loss. Code Section 1231(a). Notwithstanding the above, any gain realized may be taxed as ordinary income under one of several
“recapture” provisions of the Code or under the characterization rules relating to “dealers” in personal property. 
 Code Section 1254 generally provides for the recapture of capital gains, arising from the sale of property which was placed in service after 1986, as ordinary income to the extent of the lesser of
(i) the gain realized upon sale of the property, or (ii) the sum of (A) all IDC previously deducted and (B) all depletion deductions that reduced the property’s basis. Code Section 1254(a)(1). 

Ordinary income may also result from the recapture, pursuant to Code Section 1245, of depreciation on the Partnership properties.
Such recapture is the amount by which (i) the lower of (A) the recomputed basis of the property, or (B) the amount realized on the sale of the property exceeds (ii) the property’s adjusted basis. Code
Section 1245(a)(1). Recomputed basis is generally the property’s adjusted basis increased by depreciation and amortization deductions previously claimed with respect to the property. Code Section 1245(a)(2). 

GAIN OR LOSS ON SALE OF UNITS 
 It the Units are capital assets in the hands of the Partners, gain or loss realized by any such holders on the sale or other disposition of a Unit will be characterized as capital gain or capital loss.
Code Section 1221. Such gain or loss will be a long term capital gain or loss if the Unit is held for more than one year, or a short term capital gain or loss if held for one year or less. However, the portion of the amount realized by a
Partner in exchange for a Unit that is attributable to the Partner’s share of the Partnership’s “unrealized receivables” or “substantially appreciated inventory items” will be treated as an amount realized from the sale
or exchange of property other than a capital asset. Code Section 751. 








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 Unrealized receivables are defined in Code Section 751(c) to include
“ . . . oil [or] gas . . . property . . . to the extent of the amount which would be treated as gain to which section . . . 1245(a) . . . or 1254(a) would apply
if . . . such property had been sold by the partnership at its fair market value.” A sale by the Partnership of the Partnership’s properties could give rise to treatment of the gain thereunder as ordinary income as a result
of Code Sections 1245(a) or 1254(a). Accordingly, gain recognized by a Partner on the sale of a Unit would be taxed as ordinary income to the Partner to the extent of his share of the Partnership’s gain on property that would be
recaptured, upon sale, under those statutes. 
 Substantially appreciated inventory items are those “inventory items”
noted below, the fair market value of which exceeds 120% of the adjusted basis to the partnership of such property, excluding any such inventory property acquired with a principal purpose of avoiding Section 751. Code Section 751(d)(1).
Property treated as an “inventory item” for purposes of Code Section 751 includes (i) stock in trade of the partnership or other property of a kind which would properly be included in its inventory if on hand at the end of the
taxable year, (ii) property held by the partnership primarily for sale to customers in the ordinary course of its trade or business, and (iii) any other partnership property which would constitute neither a capital asset nor property used
in a trade or business under Code Section 1231. Code Sections 751(d)(2) and 1221(1). 
 Under the aforementioned
provisions, a Partner would recognize ordinary income with respect to any deemed sale of assets under Code Section 751; further, this ordinary income may be recognized even if the total amount realized on the sale of a Unit is equal to or less
than the Partner’s basis in the Unit. 
 Any partner who sells or exchanges interests in a partnership holding unrealized
receivables (which include IDC recapture and other items) or certain inventory items must notify the partnership of such transaction in accordance with Regulations under Code Section 6050K and must attach a statement to his tax return
reflecting certain facts regarding the sale or exchange. Regulations promulgated by the Service provide that such notice to the partnership must be given in writing within 30 days of the sale or exchange (or, if earlier, by January 15 of
the calendar year following the calendar year in which the exchange occurred), and must include names, addresses, and taxpayer identification numbers (if known) of the transferor and transferee and the date of the exchange. Code Section 6721
provides that persons who fail to furnish this information to the partnership will be penalized $50 for each such failure, or, if such failure is due to intentional disregard to the filing requirement, the person will be penalized the greater of
(i) $100 or (ii) 10% of the aggregate amount to be reported. Furthermore, a partnership is required to notify the Service of any sale or exchange of interests of which it has notice, and to report the names and addresses of the transferee
and the transferor, along with all other required information. The partnership also is required to provide copies of the information it provides to the Service to the transferor and the transferee. 








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 The tax consequences to an assignee purchaser of a Unit from a Partner are not described
herein. Any assignor of a Unit should advise his assignee to consult his own tax advisor regarding the tax consequences of such assignment. 
 PARTNERSHIP DISTRIBUTIONS 
 Under the Code, any increase in a
partner’s share of partnership liabilities, or any increase in such partner’s individual liabilities by reason of an assumption by him of partnership liabilities is considered to be a contribution of money by the partner to the
partnership. Similarly, any decrease in a partner’s share of partnership liabilities or any decrease in such partner’s individual liabilities by reason of the partnership’s assumption of such individual liabilities will be considered
as a distribution of money to the partner by the partnership. Code Section 752(a), (b). 
 The Partners’ adjusted
bases in their Units will initially consist of the cash they contribute to the Partnership. Their bases will be increased by their share of Partnership income and additional contributions and decreased by their share of Partnership losses and
distributions. To the extent that such actual or constructive distributions are in excess of a Partner’s adjusted basis in his Partnership interest (after adjustment for contributions and his share of income and losses of the Partnership), that
excess will generally be treated as gain from the sale of a capital asset. In addition, gain could be recognized to a distributee partner upon the disproportionate distribution to a partner of unrealized receivables, substantially appreciated
inventory or, in some cases, Code Section 731(c) marketable securities, i.e., actively traded financial instruments, foreign currencies or interests in certain defined properties. 

PARTNERSHIP ALLOCATIONS 
 Allocations—General. Generally, a partner’s taxable income is increased or decreased by his ratable share of partnership income or loss. Code Section 701. However, the availability of these
losses may be limited by the at risk rules of Code Section 465, the passive activity rules of Code Section 469, and the adjusted basis provisions of Code Section 704(d). 

Code Section 704(b) provides that if a partnership agreement does not provide for the allocation of each partner’s distributive
share of partnership income, gain, loss, deduction, or credit, or if the allocation of such items under the partnership agreement lacks “substantial economic effect,” then each partner’s share of those items must be allocated “in
accordance with the partner’s interest in the partnership.” 
 As discussed below, Regulations under Code
Section 704(b) define substantial economic effect and prescribe the manner in which partners’ capital accounts must be maintained in order for the allocations contained in a partnership agreement to be respected. Notwithstanding these
provisions, special rules apply with respect to nonrecourse deductions since, under the Regulations, allocations of losses or deductions attributable to nonrecourse liabilities cannot have economic effect. 








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 The Service may contend that the allocations contained in the Partnership Agreement do
not have substantial economic effect or are not in accordance with the Partners’ interests in the Partnership and may seek to reallocate these items in a manner that will increase the income or gain or decrease the deductions allocable to a
Partner. We are of the opinion that, to the extent provided herein, if challenged by the Service on this matter, the Partners’ distributive shares of Partnership income, gain, loss, deduction, or credit will be determined and allocated
substantially in accordance with the terms of the Partnership Agreement and have substantial economic effect. 
 Substantial
Economic Effect. Although a partner’s share of partnership income, gain, loss, deduction, and credit is generally determined in accordance with the partnership agreement, this share will be determined in accordance with the partner’s
interest in the partnership (determined by taking into account all facts and circumstances) and not by the partnership agreement if the partnership allocations do not have “substantial economic effect” and if the allocations are not
respected under the nonrecourse deduction provisions of the Regulations. Code Section 704(b); Reg. Sections 1.704-1(b)(2)(i), 1.704-2. 
 Regulations provide that: 
 In order for an allocation to have
economic effect, it must be consistent with the underlying economic arrangement of the partners. This means that in the event there is an economic benefit or economic burden that corresponds to an allocation, the partner to whom the allocation is
made must receive such economic benefit or bear such economic burden. 
 Reg. Section 1.704-1(b)(2)(ii). The Regulations further
provide that an allocation will have economic effect only if, throughout the full term of the partnership, the partnership agreement provides (i) for the determination and maintenance of partner’s capital accounts in accordance with
specified rules contained therein, (ii) upon liquidation of the partnership or a partner’s interest in the partnership, liquidating distributions are required to be made in accordance with the positive capital account balances of the
partners after taking into account all capital account adjustments for the taxable year of the liquidation, and (iii) either (A) a partner with a deficit balance in his capital account following the liquidation is unconditionally obligated
to restore the amount of such deficit balance to the partnership by the end of the taxable year of liquidation, or (B) the partnership agreement contains a qualified income offset (“QIO”) provision as provided in Reg.
Section 1.714-1(b)(2)(ii)(d). Reg. Sections 1.704-1(b)(2)(ii)(b) and 1.704-1(b)(2)(ii)(d). 
 The capital account
maintenance rules generally mandate that each partner’s capital account be increased by (i) money contributed by the partner to the partnership, (ii) the fair market value (net of liabilities) of property contributed by the partner to
the partnership, and (iii) allocations to the partner of partnership income and gain. Further, such capital account must be decreased by (i) money distributed to the partner from the partnership, (ii) the fair market value (net of
liabilities) of property distributed to the partner from the partnership, and (iii) allocations to the partner of partnership losses and deductions. Reg. Section 1.704-1(b)(2)(iv). 








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 Reg. Section 1.714-1(b)(2)(iii) provides that an economic effect of an allocation
is “substantial” if there is a reasonable possibility that the allocation will affect substantially the dollar amounts to be received by the partners from the partnership, independent of tax consequences. The economic effect of an
allocation is not substantial if: 
 at the time the allocation becomes part of the partnership agreement,
(1) the after-tax economic consequences of at least one partner may, in present value terms, be enhanced compared to such consequences if the allocation (or allocations) were not contained in the partnership agreement, and (2) there is a
strong likelihood that the after-tax economic consequences of no partner will, in present value terms, be substantially diminished compared to such consequences if the allocation (or allocations) were not contained in the partnership agreement. In
determining the after-tax economic benefit or detriment to a partner, tax consequences that result from the interaction of the allocation with such partner’s tax attributes that are unrelated to the partnership will be taken into account.

 Reg. 1.704-1(b)(2)(iii)(a). 
 While the Service stated that it will not rule on whether an allocation provision in a partnership agreement has substantial economic effect, several Technical Advice Memoranda (“TAMs”) shed
light on the Service’s position on such matter. Notwithstanding the potential similarity between TAMs and a taxpayer’s particular fact pattern, it should be noted that TAMs may not be used or cited as precedent. Code
Section 6110(j)(3), Treas. Reg. Sections 301.6110-2(a) and -7(b). Nevertheless, TAMs do serve to illustrate the Service’s position on certain specific cases. The TAMs relating to substantial economic effect focus on the tax avoidance
purpose of any such above-described allocations and on the partnership plan for distributions upon liquidation. Illustrative of the Service’s approach is TAM 8008054, in which the Service concluded that an allocation to the partners solely
of items that the partnership had elected to expense (IDC) had as its principal purpose tax avoidance. The Service suggested that, had the allocation affected the parties’ liquidation rights, the allocation would have had substantial economic
effect: “In general, substantial economic effect has been found where all allocations of items of income, gain, loss, deduction or credit increase or decrease the respective capital accounts of the partners and distribution of assets made upon
liquidation is made in accordance with capital accounts.” The ruling noted that the investors “should have been allocated their share of costs over the intangible drilling costs.” Id. The question whether economic effect is
“substantial” is one of fact which may depend in part on the timing of income and deductions and on consideration of the investors’ tax attributes unrelated to their investment in Units, and thus is not a question upon which a legal
opinion can ordinarily be expressed. However, to the extent the tax brackets of all Partners do not differ at the time the allocation becomes part of the partnership agreement, the economic effect of the allocation provisions should be considered to
be substantial. 








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 Code Section 613A(c)(7)(D) requires that the basis of oil and gas properties owned
by a partnership be allocated to the partners in accordance with their interests in the capital or income of the partnership. Final Regulations issued under Code Section 613A(c)(7)(D) indicate that such basis must be allocated in accordance
with the partners’ interests in the capital of the partnership if their interests in partnership income vary over the life of the partnership for any reason other than for reasons such as the admission of a new partner. Reg.
Section 1.613A-3(e)(2). The terms “capital” and “income” are not defined in the Code or in the Regulations under Section 613A. The Regulations under Code Section 704 indicate that if all partnership allocations of
income, gain, loss, and deduction (or items thereof) have substantial economic effect, an allocation of the adjusted basis of an oil or gas property among the partners will be deemed to be made in accordance with the partners’ interests in
partnership capital or income and will accordingly be recognized. 
 Pursuant to the Partnership Agreement, (i) allocations
will be made as mandated by the Regulations, (ii) liquidating distributions will be made in accordance with positive capital account balances, and (iii) a “qualified income offset” provision applies. However, while capital will
be ultimately owned by the Limited Partners in the Limited Partners’ Percentage and by the General Partner in the General Partner’s Percentage, IDC and other tax items will be allocated 99% to the Limited Partners and 1% to the General
Partner until the Limited Partner Capital Contributions are entirely expended and thereafter 100% to the General Partner. Except with respect to those excess allocations, under the Partnership Agreement, the basis in oil and gas properties will be
allocated in proportion to each Partner’s respective share of the costs which entered into the Partnership’s adjusted basis for each depletable property. Such allocations of basis appear reasonable and in compliance with the Regulations
under Section 704. Nevertheless, the Service may contend that the allocation to the Limited Partners of a percentage of Partnership IDC in excess of the Limited Partners’ Percentage or the allocation to the General Partner of other tax
items in excess of the General Partner’s Percentage is invalid and may reallocate such excess IDC or other items to the other Partners. Any such reallocation could increase a Limited Partner’s tax liability. However, no assurance can be
given, and we are unable to express an opinion, as to whether any special allocation of an item which is dependent upon basis in an oil and gas property will be recognized by the Service. 

Nonrecourse Deductions. As noted above, an allocation of loss or deduction attributable to nonrecourse liabilities of a
partnership cannot have economic effect because only the creditor bears the economic burden that corresponds to such an allocation. Nevertheless the Temporary Regulations provide a test under which certain allocations of nonrecourse deductions will
be deemed to be in accordance with the partners’ interests in the partnership. 
 Nonrecourse deduction allocations will be
deemed to be made in accordance with partners partnership interests if, and only if, four requirements are satisfied. First, the partners’ capital accounts must be maintained properly and the distribution of liquidation proceeds must be in
accordance with the partners’ capital account balances. Second, beginning in the first 








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taxable year in which there are nonrecourse deductions, and thereafter throughout the full term of the partnership, the partnership agreement must provide for allocation of nonrecourse deductions
among the partners in a manner that is reasonably consistent with allocations which have substantial economic effect of some other significant partnership item attributable to the property securing nonrecourse liabilities of the partnership. Third,
beginning in the first taxable year of the partnership in which the partnership has nonrecourse deductions or makes a distribution of proceeds of a nonrecourse liability that are allocable to an increase in minimum gain, and thereafter throughout
the full term of the partnership, the partnership agreement must contain a “minimum gain chargeback.” A partnership agreement contains a “minimum gain chargeback” if, and only if, it provides that, subject to certain exceptions,
in the event there is a net decrease in partnership minimum gain during a partnership taxable year, the partners must be allocated items of partnership income and gain for that year equal to each partner’s share of the net decrease in
partnership minimum gain during such year. A partner’s share of the net decrease in partnership minimum gain is the amount of the total net decrease multiplied by the partner’s percentage share of the partnership’s minimum gain at the
end of the immediately preceding taxable year. A partner’s share of any decrease in partnership minimum gain resulting from a revaluation of partnership property (which would not cause a minimum gain chargeback) equals the increase in the
partner’s capital account attributable to the revaluation to the extent the reduction in minimum gain is caused by such revaluation. Similar rules apply with regard to partner nonrecourse liabilities and associated deductions. The fourth
requirement of the nonrecourse allocation test provides that all other material allocations and capital account adjustments under the partnership agreement must be recognized under the general allocation requirements of the Regulations under IRC
Section 704(b). 
 Under the Regulations, partners generally share nonrecourse liabilities in accordance with their
interests in partnership profits. However, the Regulations generally require that nonrecourse liabilities be allocated among the partners first to reflect the partners’ share of minimum gain and Code Section 704(c) minimum gain. Any
remaining nonrecourse liabilities are generally to be allocated in proportion to the partners’ interests in partnership profits. 
 The Partnership Agreement contains a minimum gain chargeback. Further, the Partnership Agreement provides for the allocation of nonrecourse liabilities and deductions attributable thereto among the
Partners first, in accordance with their respective shares of partnership minimum gain (within the meaning of Reg. Section 1.704-2(b)(2)); second, to the extent of each such Partner’s gain under Code Section 704(c) if the Partnership
were to dispose of (in a taxable transaction) all Partnership property subject to one or more nonrecourse liabilities of the Partnership in full satisfaction of such liabilities and for no other consideration; and third, in accordance with the
Partners’ proportionate shares in the Partnership’s profits. Reg. Section 1.752-3. For this purpose, the Partnership Agreement provides for the allocation of excess nonrecourse deductions in the Limited Partners’ Percentage to
the Limited Partners and in the General Partner’s Percentage to the General Partner. 








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 Retroactive Allocations. To prevent retroactive allocations of partnership tax
attributes to partners entering into a partnership late in the tax year, Code Section 706(d) provides that a partner’s distributive share of such attributes is to be determined by the use of methods prescribed by the Secretary of the
Treasury which take into account the varying interests of the partners during the taxable year. The Partnership Agreement provides that each Partner’s allocation of tax items other than “allocable cash basis items” is to be determined
under a method permitted by Code Section 706(d) and the Regulations thereunder. 
 TAX AUDITS 

Subchapter C of Chapter 63 of the Code provides that administrative proceedings for the assessment and collection of tax
deficiencies attributable to a partnership must be conducted at the partnership, rather than the partner, level. Partners will be required to treat Partnership items of income, gain, loss, deduction, and credit in a manner consistent with the
treatment of each such item on the Partnership’s returns unless such Partner files a statement with the Service identifying the inconsistency. If the Partnership is audited, the tax treatment of each item will be determined at the Partnership
level in a unified partnership proceeding. Conforming adjustments to the Partners’ own returns will then occur unless such partner can establish a basis for inconsistent treatment (subject to waiver by the Service). 

The General Partner will be designated the “tax matters partner” (“TMP”) for the Partnership and will receive notice
of the commencement of a Partnership proceeding and notice of any administrative adjustments of Partnership items. The TMP is entitled to invoke judicial review of administrative determinations and to extend the period of limitations for assessment
of adjustments attributable to Partnership items. Each Partner will receive notice of the administrative proceedings from the TMP and will have the right to participate in the administrative proceeding pursuant to tax requirements of Reg.
Section 301.6223(g) unless the Partner waives such rights. 
 The Code provides that, subject to waiver, partners will
receive notice of the administrative proceedings from the Service and will have the right to participate in the administrative proceedings. However, the Code also provides that if a partnership has 100 or more partners, the partners with less than a
1% profits interest will not be entitled to receive notice from the Service or participate in the proceedings unless they are members of a “notice group” (a group of partners having in the aggregate a 5% or more profits interest in the
partnership that requires the Service to send notice to the group and that designates one of their members to receive notice). Any settlement agreement entered into between the Service and one or more of the partners will be binding on such partners
but will not be binding on the other partners, except that settlement by the TMP may be binding on certain partners, as described below. The Service must, on request, offer consistent settlement terms to the partners who had not entered into the
earlier settlement agreement. If a partnership has more than 100 partners, the TMP is empowered under the Code to enter into binding settlement agreements on behalf of the partners with a less than 1% profits interest unless the partner is a member
of a notice group or notifies the Service that the TMP does not have the authority to bind the partner in such a settlement. 








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 The costs incurred by a Partner in responding to an administrative proceeding will be
borne solely by such Partner. 
 PENALTIES 
 An additional tax equal to 20% of the amount of any portion of an underpayment of tax that is attributable to one or more specified causes, including negligence or disregard of rules or Regulations,
substantial understatements of income tax and substantial valuation misstatements, is imposed by the Internal Revenue Code. No penalty will be imposed, however, for any portion of an underpayment if it is shown that there was a reasonable cause for
that portion and that the taxpayer acted in good faith regarding that portion. 
 For individuals, a substantial understatement
of income tax in any taxable year exists if the amount of the understatement exceeds the greater of 10% of the tax required to be shown on the return for the taxable year or $5,000 ($10,000 for most corporations). The amount of any understatement
subject to penalty generally is reduced if any portion is attributable to a position adopted on the return: 
 (1) for which
there is, or was, “substantial authority”; or 
 (2) as to which there is a reasonable basis and the pertinent facts
of that position are disclosed on the return. 
 If any item of income, gain, loss or deduction included in the distributive
shares of the Limited Partners might result in that kind of an “understatement” of income for which no “substantial authority” exists, the Partnership must disclose the pertinent facts on its return. In addition, the Partnership
will make a reasonable effort to furnish sufficient information for the Limited Partners to make adequate disclosure on their returns and to take other actions as may be appropriate to permit them to avoid liability for this penalty. More stringent
rules apply to “tax shelters.” We do not believe the Partnership is a “tax shelter” for these purposes. 

For individuals, a substantial valuation misstatement exists if the value of any property, or the adjusted basis of any property, claimed
on a tax return is 150% or more of the amount determined to be the correct amount of the valuation or adjusted basis. No penalty is imposed unless the portion of the underpayment attributable to a substantial valuation misstatement exceeds $5,000
($10,000 for most corporations). If the valuation or adjusted basis claimed on a return is 200% or more than the correct valuation or adjusted basis, the penalty imposed increases to 40%. 








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 Reportable Transactions. If the Partnership were to engage in a “reportable
transaction,” it (and possibly the Limited Partners and others) would be required to make a detailed disclosure of the transaction to the IRS. A transaction may be a reportable transaction based upon any of several factors, including the fact
that it is a type of tax avoidance transaction publicly identified by the IRS as a “listed transaction” or that it produces certain kinds of losses for partnerships, individuals, S corporations, and trusts in excess of $2 million in any
single year or $4 million in any combination of 6 successive tax years. The Partnerhsip’s participation in a reportable transaction could increase the likelihood that its federal income tax information return (and possibly our Limited
Partners’ tax returns) would be audited by the IRS. 
 Moreover, if the Partnership were to participate in a reportable
transaction with a significant purpose to avoid or evade tax, or in any listed transaction, the Limited Partners may be subject to the following provisions of the American Jobs Creation Act of 2004: 

 

	 	•	 	 accuracy-related penalties with a broader scope, significantly narrower exceptions, and potentially greater amounts than described above at;”



  

	 	•	 	 for those persons otherwise entitled to deduct interest on federal tax deficiencies, nondeductibility of interest on any resulting tax liability; and



  

	 	•	 	 in the case of a listed transaction, an extended statute of limitations. 



There may not be substantial authority for one or more reporting positions that the Partnership may take in its federal income tax
returns. In such event, if the Partnership does not disclose or if it fails to adequately disclose any such position, or if such disclosure is deemed adequate but it is determined that there was no reasonable basis for the tax treatment of such a
partnership item, the penalty will be imposed with respect to any substantial understatement determined to have been made, unless the provisions of the Regulations pertaining to waiver of the penalty become final and the Partnership is able to show
reasonable cause and good faith in making the understatement as specified in such provisions. If the Partnership makes a disclosure for the purposes of avoiding the penalty, the disclosure is likely to result in an audit of such return and a
challenge by the Service of such position taken. 
 If it were determined that a Partner had underpaid tax for any taxable year,
such Partner would have to pay the amount of underpayment plus interest on the underpayment from the date the tax was originally due. The interest rate on underpayments is determined by the Service based upon the federal short term rate of interest
(as defined in Code Section 1274(d)) plus 3%, or 5% for large corporate underpayments, and is compounded daily. The rate of interest is adjusted monthly. In addition, temporary Regulations provide that tax motivated transactions include, among
other items, certain overstatements of the value of property on a return, losses disallowed by reason of the at-risk limitation any use of an accounting method that may result in a substantial distortion of income for any period, and any deduction
disallowed for an activity not entered into for profit. The determination of those transactions to be considered 








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“tax-motivated transactions” is to be made by taking into account the ratio of tax benefits to cash invested, the method of promoting the transaction, and other relevant transactions.
Thus, in the event an audit of the Partnership’s or of a Partner’s tax return results in a substantial underpayment of tax by such Partner due to an investment in the Units, such Partner may be required to pay interest on such underpayment
determined at the higher interest rate. 
 A partnership, for federal income tax purposes, is required to file an annual
informational tax return. The failure to properly file such a return in a timely fashion, or the failure to show on such return all information under the Code to be shown on such return, unless such failure is due to reasonable cause, subjects the
partnership to civil penalties under the Code in an amount equal to $50 per month multiplied by the number of partners in the partnership, up to a maximum of $250 per partner per year. In addition, upon any willful failure to file a partnership
information return, a fine or other criminal penalty may be imposed on the party responsible for filing the return. 
 As
noted above under the heading “IMPORTANT LIMITATIONS ON TAX ASPECTS — LIMITED SCOPE OPINION DISCLAIMER,” the Letter was not intended or written to be used, and cannot be used, for the purpose of avoiding penalties that may be imposed
by the Service with respect to any federal tax issues not addressed therein. 
 ACCOUNTING METHODS AND PERIODS

 The Partnership will use the accrual method of accounting and will select the calendar year as its taxable year.

 As discussed above, a taxpayer using the accrual method of accounting will recognize income when all events have occurred
which fix the right to receive such income and the amount thereof can be determined with reasonable accuracy. Deductions will be recognized when all events which establish liability have occurred and the amount thereof can be determined with
reasonable accuracy. However, all events which establish liability are not treated as having occurred prior to the time that economic performance occurs. Code Section 461(h). 

All partnerships are required to conform their tax years to those of their owners; i.e., unless the partnership establishes a business
purpose for a different tax year, the tax year of a partnership must be (i) the taxable year of one or more of its partners who have an aggregate interest in partnership profits and capital of greater than 50%, (ii) if there is no taxable
year so described, the taxable year of all partners having interests of 5% or more in partnership profits or capital, or (iii) if there is no taxable year described in (i) or (ii), the calendar year. Code Section 706. Until the
taxable years of the Partners can be identified, no assurance can be given that the Service will permit the Partnership to adopt a calendar year. 








 CONNER & WINTERS, LLP 
 Unit Petroleum Company 
 December 30, 2010 
 Page 39 
  

 STATE AND LOCAL TAXES 

The opinions expressed herein are limited to issues of federal income tax law and do not address issues of state or local law. Investors
are urged to consult their tax advisors regarding the impact of state and local laws on an investment in the Partnership. 
 We
express no opinion as to any federal income tax issue or other matter except those set forth or confirmed above. 
 We hereby
consent to the filing of this opinion as Exhibit B to the Memorandum and to all references to our firm in the Memorandum. 
  

	
	Sincerely,
	
	 /s/ Conner & Winters, LLP

	Conner & Winters, LLP