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**UNITED STATES**

**SECURITIES AND EXCHANGE COMMISSION**

**Washington, D.C. 20549**

 

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**Form 10-K**

 

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**(Mark One)**

 

**x****      ANNUAL REPORT PURSUANT TO SECTION 13 or 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934**

 

**For The Fiscal Year Ended December 31, 2010**

 

**or**

 

**o****         TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934**

 

**For the Transition period from                to               **

 

**COMMISSION FILE NUMBER 333-122935-01**

 

**REEF GLOBAL ENERGY VI, L.P.**

(Exact name of registrant as specified in its charter)

** **

| **Nevada**                                                      | ** ** | **20-3170768**                        |
|-----------------------------------------------------------------|------------|---------------------------------------|
| (State or other jurisdiction of

incorporation or organization) |       | (I.R.S. Employer

Identification No.) |

 

**1901 N. Central Expressway, Suite 300, Richardson, TX 75080-3610**

(Address of principal executive offices including zip code)

 

**(972)-437-6792**

(Registrant’s telephone number, including area code)

 

Securities registered pursuant to Section 12(b) of the Act: **None**

 

Securities registered pursuant to Section 12(g) of the Act:

 

**General and Limited Partnership Interests**

(Title of Class)

 

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.  Yes o  No x

 

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.  Yes  o  No x

 

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.  Yes x  No o

 

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

 

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.  x

 

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

 
| Large accelerated filer o |   | Accelerated filer o         |
|---------------------------|--------|-----------------------------|
|                      |   |                        |
| Non-accelerated filer o   |   | Smaller reporting company x |

 

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

 

No market currently exists for the limited and general partnership interests of the registrant.

 

As of March 31, 2011, the registrant had 75.363 units of general partner interest held by the managing general partner, and 1,431.897 units of limited partner interest outstanding.

 

Documents incorporated by reference:  None

 

 

 

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REEF GLOBAL ENERGY VI, L.P.

ANNUAL REPORT ON FORM 10-K FOR THE YEAR ENDED DECEMBER 31, 2010

TABLE OF CONTENTS

 
| **Part I**   | ** **                                                                                                          | ** ** |
|-------------------|---------------------------------------------------------------------------------------------------------------------|------------|
| ** **        | ** **                                                                                                          | ** ** |
| Item 1.           | Business                                                                                                            |       |
| Item 1A.          | Risk Factors                                                                                                        |       |
| Item 1B.          | Unresolved Staff Comments                                                                                           |       |
| Item 2.           | Properties                                                                                                          |       |
| Item 3.           | Legal Proceedings                                                                                                   |       |
| Item 4.           | (Removed and Reserved)                                                                                              |       |
|              |                                                                                                                |       |
| **PART II**  |                                                                                                                |       |
|              |                                                                                                                |       |
| Item 5.           | Market for Registrant’s Common Equity,   Related Stockholder Matters and Issuer Purchases of Equity Securities |       |
| Item 6.           | Selected Financial Data                                                                                             |       |
| Item 7.           | Management’s Discussion and Analysis of   Financial Condition and Results of Operations                        |       |
| Item 7A.          | Quantitative   and Qualitative Disclosure About Market Risk                                                         |       |
| Item 8.           | Financial   Statements and Supplementary Data                                                                       |       |
| Item 9.           | Changes in and Disagreements with   Accountants on Accounting and Financial Disclosure                              |       |
| Item 9A.          | Controls and Procedures                                                                                             |       |
| Item 9B.          | Other Information                                                                                                   |       |
|              |                                                                                                                |       |
| **PART III** |                                                                                                                |       |
|              |                                                                                                                |       |
| Item 10.          | Directors,   Executive Officers and Corporate Governance                                                            |       |
| Item 11.          | Executive Compensation                                                                                              |       |
| Item 12.          | Security Ownership of Certain   Beneficial Owners and Management and Related Stockholder Matters                    |       |
| Item 13.          | Certain Relationships and   Related Transactions, and Director Independence                                         |       |
| Item 14.          | Principal   Accountant Fees and Services                                                                            |       |
|              |                                                                                                                |       |
| **PART IV**  |                                                                                                                |       |
|              |                                                                                                                |       |
| Item 15.          | Exhibits and   Financial Statement Schedules                                                                        |       |
|              | Signatures                                                                                                          |       |

 

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**PART I**

 

**ITEM 1.                   BUSINESS**

 

**Introduction**

 

Reef Global Energy VI, L.P. (the Partnership) is the first in a series of four Nevada limited partnerships comprising a program called Reef Global Energy Ventures II (the Program). The Partnership was formed in the state of Nevada on July 18, 2005.  The Partnership purchased working interests in oil and gas prospects and participated in the drilling of wells on those prospects. The primary objectives of the Partnership are to generate revenue from the production of crude oil and natural gas, distribute cash to the partners, and provide tax benefits. Reef Oil & Gas Partners, L.P. (Reef) is the managing general partner of the Partnership.

 

The Partnership was formed to drill, complete and own working interests in oil and gas wells located onshore in the continental United States or in U.S. coastal waters in the Gulf of Mexico. The Partnership purchased working interests in twenty developmental prospects (as defined below) upon which it drilled twenty-seven developmental wells. The Partnership purchased working interests in fourteen exploratory prospects upon which it drilled sixteen exploratory and eight developmental wells. These prospects are located onshore in Texas, Louisiana, Oklahoma, New Mexico and in U.S. coastal waters in the Gulf of Mexico. In 2008, the Partnership completed drilling operations with the capital previously raised by the Partnership. The Partnership will not purchase additional prospects. In accordance with the Partnership’s limited partnership agreement (the Partnership Agreement), the Partnership may conduct additional drilling operations to fully develop those prospects already owned by the Partnership.

 

Other partnerships formed as a part of the Program also own working interests in some of the prospects owned by this Partnership. Reef also purchased working interests in certain partnership prospects for some of the other partnerships it manages. In instances where the percentage ownership of the Partnership and Reef-affiliated entities in a prospect is large enough, Reef Exploration, L.P. (RELP), an affiliate of Reef formed in 2005, serves as operator of the prospect. RELP serves as operator of eight developmental and four exploratory Partnership prospects. RELP operates nine successful developmental wells, one of which has been converted to a salt water disposal well, and two successful exploratory wells.  In this Annual Report on Form 10-K (Annual Report), we use the term “successful” to refer to wells that are drilled, tested, and either capable of or actually producing in commercial quantities. We use the term “unsuccessful” to refer to wells that do not meet one or more of these criteria.

 

**Acquisition and Drilling of Undeveloped Prospects**

 

The Partnership purchased working interests in eight developmental and four exploratory prospects internally sourced by RELP, and twelve developmental and ten exploratory prospects generated by and purchased from third parties. A “prospect” is generally defined as a contiguous oil and gas leasehold estate, or lesser interest in a leasehold estate, upon which drilling operations may be conducted. A prospect may be characterized as “exploratory” or “developmental” based upon the type of well to be drilled on the prospect.  A developmental well is a well drilled within a proved area of an oil or gas reservoir to the depth of a stratigraphic horizon known to be productive. Generally an exploratory well is any well that is not a developmental well, including wells drilled to find and produce crude oil or natural gas in an unproven area, wells drilled to find a new reservoir in a field previously found to be productive of crude oil or natural gas, or wells drilled to extend a known reservoir.

 

Prospects were evaluated utilizing data generated by RELP or provided by unaffiliated third parties to RELP. This data included well logs, production records from other area wells, seismic, geological and geophysical information, and such other information available and considered useful. Prospects in which the Partnership purchased a working interest were evaluated by petroleum engineers, geophysicists, geologists, and other technical consultants employed by or retained by RELP on the Partnership’s behalf.

 

The Partnership prospects were acquired pursuant to an arrangement in which the Partnership purchased part of the working interest. A working interest bears a specified portion of the costs of development, operation and maintenance.  A working interest is subject to landowners’ royalty interests and may be subject to other royalty interests payable to unaffiliated third parties. Where the Partnership acquired less than 100% of the working interest, costs were reduced proportionately. The Partnership Agreement prohibits Reef or any of its affiliates from retaining 

 

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any overriding royalty interest, that is, any royalty interest that would be paid out of the Partnership’s working interest, in any working interest purchased by the Partnership. The Partnership is a non-operator working interest owner in all prospects purchased by the Partnership.

 

**Drilling and Completion Phase of Operations**

 

On all prospects currently operated by RELP, drilling operations were contracted to independent third party drillers, and the costs of the wells to the Partnership were determined by actual third party costs, plus monthly operator fees charged at the competitive rate for the geographical area where the wells are located.

 

The Partnership generally pays drilling and completion costs as incurred. Wells drilled that fail to result in the discovery of commercial quantities of crude oil or natural gas are plugged and abandoned in accordance with applicable regulations.  Twelve development wells and eight exploratory wells in which the Partnership participated in drilling operations were unsuccessful. Twenty-three developmental and eight exploratory wells in which the Partnership participated in drilling operations were successful. Of these wells, nineteen are currently producing, one has been converted to a salt water disposal well, two have been sold, eight have been plugged and abandoned, and one is currently shut-in awaiting plugging.

 

RELP is currently the operator of eight developmental and four exploratory prospects, and serves as operator of eleven successful wells in which the Partnership has a working interest, including the eight wells located on the Sand Dunes prospect discussed in more detail in Item 2 - Properties. As a well operator, RELP receives operator fees during the drilling and production phase of each well at the competitive rate in the geographical area where the prospect is located.  These fees are charged as a monthly fee per well as agreed to in an operating agreement signed by the Partnership and participating third parties in the well. The wells are subject to a model form operating agreement issued by the American Association of Petroleum Landmen and an accounting procedure for joint operations issued by the Council of Petroleum Accountants Societies of North America.

 

**Production Phase of Operations**

 

Wells capable of producing quantities of crude oil and/or natural gas in commercial quantities were completed by installing all surface equipment necessary to control the flow of production or to shut down the well, and by installing any storage facilities, gathering lines, or sales lines required to produce and sell the crude oil and/or natural gas production from the well. The Partnership participated in drilling twenty-three successful developmental wells, including the eight wells located on the Sand Dunes prospect discussed in more detail in Item 2 — Properties, and eight successful exploratory wells. Of these wells, nineteen are currently producing, one has been converted to a salt water disposal well, two have been sold, eight have been plugged and abandoned, and one is currently shut-in awaiting plugging.

 

The Partnership has entered into agreements with third party marketers to sell the crude oil and/or natural gas produced from successful wells on a competitive basis at the best available terms and prices.  In some cases the Partnership has elected to sell its production under marketing arrangements entered into by the operator of the well. Generally, purchase contracts for the sale of crude oil are cancelable on 30 days’ notice, but purchase contracts for the sale of natural gas may have a longer term.  The Partnership sells natural gas discovered by it at negotiated prices domestically, based upon a number of factors, such as the quality of the gas, well pressure, estimated reserves, prevailing supply conditions and any applicable price regulations promulgated by the Federal Energy Regulatory Commission (FERC).

 

Historically, the oil and gas market has experienced significant price fluctuations. Prices are impacted by local weather, supply in the area, availability and price of competitive fuels, seasonal variations in local demand, limited transportation capacity to other regions, and the worldwide supply and demand balance for crude oil.

 

The Partnership has not and does not expect to engage in commodity futures trading or hedging activities, or enter into derivative financial instrument transactions for trading or other speculative purposes. Accordingly, the Partnership is at risk for the volatility in commodity prices inherent in the oil and gas industry, and the level of commodity prices has a significant impact on the Partnership’s results of operations.  See “Item 7A. Quantitative and Qualitative Disclosure About Market Risk.”

 

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The Partnership’s share of revenue from productive wells is burdened by and/or subject to royalties and overriding royalties, monthly operating charges, and other operating costs.  These items of expenditure involve amounts payable solely out of, or expenses incurred solely by reason of, production operations.  The Partnership deducts operating expenses from the production revenue for the corresponding period.

 

**Major Customers**

 

The Partnership sells crude oil and natural gas on credit terms to refiners, pipelines, marketers, and other users of petroleum commodities. Revenues are received directly from these parties or, in certain circumstances, paid to the operator of the property who disburses to the Partnership its percentage share of the revenues. During the year ended December 31, 2010, one marketer and one operator accounted for 57.6% and 33.3% of the Partnership’s crude oil and natural gas revenues, respectively. During the year ended December 31, 2009, one marketer and one operator accounted for 51.3% and 31.2% of the Partnership’s crude oil and natural gas revenues, respectively. During the year ended December 31, 2008, one marketer and two operators accounted for 57.2%, 17.4%, and 11.4% of the Partnership’s crude oil and natural gas revenues, respectively. Due to the competitive nature of the market for purchase of crude oil and natural gas, the Partnership does not believe that the loss of any particular purchaser would have a material adverse impact on the Partnership.

 

**Insurance**

 

The Partnership is a named insured under blowout, pollution, public liability and workmen’s compensation insurance policies obtained by RELP. Such insurance, however, may not be sufficient to cover all liabilities.  Each unit held by general partners represents an open-ended security for unforeseen events including, without limitation, blowouts, lost circulation, and stuck drill pipe that may result in unanticipated additional liability materially in excess of a general partner’s initial investment in the Partnership.

 

The Partnership is a named insured under various insurance policies and intends to maintain such policies subject to its analysis of their premium costs, coverage and other factors.  In the exercise of Reef ‘s fiduciary duty as managing general partner, Reef has obtained insurance on behalf of the Partnership to provide the Partnership with such coverage as Reef believes is sufficient to protect the investor partners against the foreseeable risks of drilling and production.  Reef reviewed the Partnership insurance coverage prior to commencing drilling operations and periodically evaluates the sufficiency of insurance. In no event will the Partnership maintain public liability insurance of less than two times the Partnership’s capitalization.****Subject to the foregoing, Reef may, in its sole discretion, increase or decrease the policy limits and types of insurance from time to time as Reef deems appropriate under the circumstances, which may vary materially.

 

In accordance with the Partnership Agreement of the Partnership, all general partner units held by investors were converted into limited partner units during the third quarter of 2008. At that time, Reef amended the Certificate of Limited Partnership to effectuate the conversion of the interest of the former non-Reef general partners to that of a limited partner. Non-Reef general partners will have limited liability as a limited partner for any Partnership operations conducted after their conversion date. However, non-Reef general partners that converted to limited partners continue to have unlimited liability regarding partnership activities that occurred prior to their conversion date.

 

**Competition**

 

There are thousands of oil and gas companies in the United States.  Competition is strong among persons and entities involved in the exploration for and production of crude oil and natural gas.  Reef expects the Partnership to encounter strong competition at every phase of business.  The Partnership competes with entities having financial resources and staffs substantially larger than those available to it.

 

The national supply of natural gas is widely diversified, with no one entity controlling over 5% of the supply.  As a result of deregulation of the natural gas industry enacted by Congress and FERC, natural gas prices are generally determined by competitive market forces.  Prices of crude oil, condensate and natural gas liquids are not currently regulated and are generally determined by competitive market forces.

 

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**Markets**

 

The marketing of crude oil and natural gas produced by the Partnership is affected by a number of factors that are beyond the Partnership’s control and whose exact effect cannot be accurately predicted.  These factors include:

 
| · |   | the   amount of crude oil and natural gas imports;                                                                                                                      |
|--------|--------|-------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| · |   | the   availability, proximity and cost of adequate pipeline and other   transportation facilities;                                                                      |
| · |   | the success of efforts to market competitive   fuels, such as coal and nuclear energy and the growth and/or success of   alternative energy sources such as wind power; |
| · |   | the   effect of United States and state regulation of production, refining,   transportation and sales;                                                                 |
| · |   | other   matters affecting the availability of a ready market, such as fluctuating   supply and demand; and                                                              |
| · |   | general   economic conditions in the United States and around the world.                                                                                                |

 

The supply and demand balance of crude oil and natural gas in world markets has caused significant variations in the prices of these products over recent years.  The North American Free Trade Agreement eliminated trade and investment barriers between the United States, Canada, and Mexico, resulting in increased foreign competition for domestic natural gas production.  New pipeline projects recently approved by, or presently pending before, FERC, as well as nondiscriminatory access requirements could further substantially increase the availability of gas imports to certain U.S. markets.  Such imports could have an adverse effect on both the price and volume of natural gas sales from Partnership wells.

 

Members of the Organization of Petroleum Exporting Countries (OPEC) establish prices and production quotas for petroleum products from time to time with the intent of affecting the global supply of crude oil and reducing, increasing or maintaining certain price levels.  Reef is unable to predict what effect, if any, such actions will have on the amount of or the prices received for crude oil produced and sold from the Partnership’s wells.

 

In several initiatives, FERC has required pipelines to develop electronic communication and to provide standardized access via the Internet to information concerning capacity and prices on a nationwide basis, so as to create a national market.  Parallel developments toward an electronic marketplace for electric power, mandated by FERC, are serving to create multi-national markets for energy products generally.  These systems will allow rapid consummation of natural gas transactions.  Although this system may initially lower prices due to increased competition, it is anticipated to expand natural gas markets and to improve their reliability.

 

**Regulation**

 

The Partnership’s operations will be affected from time to time in varying degrees by domestic and foreign political developments, and by federal and state laws and regulations.

 

*Regulation of Oil & Gas Activities.*  In most areas of operations within the United States the production of crude oil and natural gas is regulated by state agencies that set allowable rates of production and otherwise control the conduct of oil and gas operations. Operators of oil and gas properties are required to have a number of permits to operate such properties, including operator permits and permits to dispose of salt water. RELP possesses all material requisite permits required by the states and other local authorities in areas where it operates properties.  States control production through regulations that establish the spacing of wells or limit the number of days in a given month a well can produce.  In addition, under federal law, operators of oil and gas properties are required to possess certain certificates and permits such as hazardous materials certificates, which RELP has obtained.

 

*Environmental Matters.*  The Partnership’s drilling and production operations are also subject to environmental protection regulations established by federal, state, and local agencies that may necessitate significant capital outlays that, in turn, would materially affect the financial position and business operations of the Partnership. These regulations, enacted to protect against waste, conserve natural resources and prevent pollution, could necessitate spending funds on environmental protection measures, rather than on drilling operations. If any penalties or prohibitions were imposed on the Partnership for violating such regulations, the Partnership’s operations could be adversely affected.

 

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*Climate Change Legislation and Greenhouse Gas Regulation.*Studies in recent years have indicated that emissions of certain gases may be contributing to warming of the Earth’s atmosphere. Many nations have agreed to limit emissions of greenhouse gases (GHGs) pursuant to the United Nations Framework Convention on Climate Change, and the Kyoto Protocol. Methane, a primary component of natural gas, and carbon dioxide, a byproduct of the burning of crude oil, natural gas, and refined petroleum products, are considered GHGs regulated by the Kyoto Protocol. Although the United States is currently not participating in the Kyoto Protocol, several states have adopted legislation and regulations to reduce emissions of GHGs. Restrictions on emissions of methane or carbon dioxide that may be imposed in various states could adversely affect our operations and demand for crude oil and natural gas. On December 7, 2009, the Environmental Protection Agency (EPA) issued a finding that serves as the foundation under the Clean Air Act to issue rules that would result in federal GHGs regulations and emissions limits under the Clean Air Act, even without Congressional action. On September 29, 2009, the EPA also issued a GHG monitoring and reporting rule that requires certain parties, including participants in the oil and gas industry, to monitor and report their GHG emissions, including methane and carbon dioxide, to the EPA. The emissions will be published on a register to be made available on the Internet. These regulations may apply to our operations. The EPA has proposed two other rules that would regulate GHGs, one of which would regulate GHGs from stationary sources, and may affect the oil and gas exploration and production industry and the pipeline industry. The EPA’s finding, the GHG reporting rule, and the proposed rules to regulate the emissions of GHGs would result in federal regulation of carbon dioxide emissions and other GHGs, and may affect the outcome of other climate change lawsuits pending in United States federal courts in a manner unfavorable to the oil and gas industry.

 

*Natural Gas Transportation and Pricing.*  FERC regulates the rates for interstate transportation of natural gas as well as the terms for access to natural gas pipeline capacity. Pursuant to the Wellhead Decontrol Act of 1989, however, FERC may not regulate the price of natural gas. Such deregulated natural gas production may be sold at market prices determined by supply and demand, Btu content, pressure, location of wells, and other factors. Reef anticipates that all of the natural gas produced by the Partnership’s wells will be considered price-decontrolled natural gas and that the Partnership’s natural gas will be sold at fair market value.  However, while sales by producers of natural gas can currently be made at unregulated market prices, Congress could reenact price controls in the future.

 

*Proposed Regulation.*Various legislative proposals are being considered in Congress and in the legislatures of various states, which, if enacted, may significantly and adversely affect the petroleum and gas industries. Such proposals involve, among other things, the imposition of price controls on all categories of natural gas production, the imposition of land use controls, such as prohibiting drilling activities on certain federal and state lands in protected areas, as well as other measures. At the present time, it is impossible to predict what proposals, if any, will actually be enacted by Congress or the various state legislatures and what effect, if any, such proposals will have on the Partnership’s operations.

 

**Employees**

 

The Partnership has no employees, and is managed by its managing general partner, Reef. RELP employs a staff including geologists, petroleum engineers, landmen, and accounting personnel who administer all of the Partnership’s operations. The Partnership reimburses RELP for technical and administrative services at cost.  See “Item 11- Executive Compensation.”

 

**FORWARD-LOOKING STATEMENTS**

 

This Annual Report contains forward-looking statements that involve risks and uncertainties.  You should exercise extreme caution with respect to all forward-looking statements made in this Annual Report.  Specifically, the following statements are forward-looking:

 
| · |   | statements   regarding the Partnership’s overall strategy for acquiring prospects,   including its intent to diversify the Partnership’s investments;                 |
|--------|--------|---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| · |   | statements   estimating any number or specific type or size of prospects the Partnership   may acquire or size of the interest the Partnership may acquire in such   prospects; |

 

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| · |   | statements   regarding the state of the oil and gas industry and the opportunity to profit   within the oil and gas industry, competition, pricing, level of production,   or the regulations that may affect the Partnership;                                              |
|--------|--------|-----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| · |   | statements   regarding the plans and objectives of Reef for future operations, including,   without limitation, the uses of Partnership funds and the size and nature of   the costs the Partnership expects to incur and people and services the   Partnership may employ; |
| · |   | any   statements using the words “anticipate,” “believe,” “estimate,” “expect” and   similar such phrases or words; and                                                                                                             |
| · |   | any   statements of other than historical fact.                                                                                                                                                                                                                             |

 

Reef believes that it is important to communicate its future expectations to the partners.  Forward-looking statements reflect the current view of management with respect to future events and are subject to numerous risks, uncertainties and assumptions, including, without limitation, the factors listed in ITEM 1A of this Annual Report captioned “RISK FACTORS.” Although Reef believes that the expectations reflected in such forward-looking statements are reasonable, Reef can give no assurance that such expectations will prove to have been correct.  Should any one or more of these or other risks or uncertainties materialize or should any underlying assumptions prove incorrect, actual results are likely to vary materially from those described herein.  There can be no assurance that the projected results will occur, that these judgments or assumptions will prove correct or that unforeseen developments will not occur.

 

Reef does not intend to update its forward-looking statements.  All subsequent written and oral forward-looking statements attributable to Reef or persons acting on its behalf are expressly qualified in their entirety by the applicable cautionary statements.

 

**ITEM 1A.                RISK FACTORS**

 

Our business activities are subject to certain risks and hazards, including the risks discussed below. If any of these events should occur, it could materially and adversely affect our business, financial condition, cash flow, or results of operations. The risks below are not the only risks we face. We may experience additional risks and uncertainties not currently known to us or, as a result of developments occurring in the future, conditions that we currently deem to be immaterial may also materially and adversely affect our business, financial condition, cash flow, and results of operations.  Consequently, you should not consider this list to be a complete statement of all of our potential risks or uncertainties.

 

**Crude oil and natural gas prices are volatile, and fluctuate due to a number of factors outside of our control.**

 

The financial condition, results of operations, and the carrying value of our oil and gas properties depend primarily upon the prices received for our crude oil and natural gas production. Crude oil and natural gas prices historically have been volatile and likely will continue to be volatile given current geopolitical conditions. Cash flow from operations is highly dependent upon the sales prices received from crude oil and natural gas production. The prices for crude oil and natural gas are subject to a variety of factors beyond our control. These factors include:

 
| · |   | the   domestic and foreign supply of crude oil and natural gas; consumer demand for   crude oil and natural gas, and market expectations regarding supply and   demand; |
|--------|--------|-------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| · |   | the   ability of the members of OPEC to agree to and maintain crude oil price and   production controls;                                                                |
| · |   | domestic   government regulations and taxes;                                                                                                                            |
| · |   | the   price and availability of foreign exports and alternative fuel sources;                                                                                           |
| · |   | weather   conditions, including hurricanes and tropical storms in and around the Gulf   of Mexico;                                                                      |
| · |   | political   conditions in crude oil and natural gas producing regions, including the   Middle East, Nigeria, and Venezuela; and                                         |
| · |   | domestic   and worldwide economic conditions.                                                                                                                           |

 

These factors and the volatility of the energy markets make it extremely difficult to predict price movements. Also, crude oil and natural gas prices do not necessarily move in tandem. Declines in crude oil and natural gas prices would not only reduce revenues and cash flow available for distributions to partners, but could reduce the amount of crude oil and natural gas that can be economically produced from successful wells drilled by the Partnership, and, 

 

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therefore, have an adverse effect upon financial condition, results of operations, crude oil and natural gas reserves, and the carrying value of the Partnership’s oil and gas properties. Approximately 73.0% of the Partnership’s estimated proved reserves at December 31, 2010 were natural gas, and, as a result, financial results are more sensitive to fluctuations in natural gas prices.

 

The Partnership, while not prohibited from engaging in commodity trading or hedging activities in an effort to reduce exposure to short-term fluctuations in the price of crude oil and natural gas, has not engaged in such activities. Accordingly, the Partnership is at risk for the volatility in crude oil and natural gas prices, and the level of commodity prices has a significant impact upon the Partnership’s results of operations.

 

**The recent global economic downturn could have a material adverse impact on our financial position, results of operations and cash flows.**

 

The oil and gas industry is cyclical and tends to reflect general economic conditions. The United States and other countries around the world experienced an economic downturn in 2008 and 2009 which could continue to impact the industry in 2011 and beyond. The economic downturn has had an adverse impact on demand and pricing for crude oil and natural gas. A continuation of the economic downturn could have a further negative impact on crude oil and natural gas prices. The Partnership’s operating cash flows and profitability will be significantly affected by declining crude oil and natural gas prices. Further declines in crude oil and natural gas prices may also impact the value of our crude oil and natural gas reserves, which could result in future impairment charges to reduce the carrying value of the Partnership’s oil and gas properties.

 

**We are subject to substantial operating risks that may adversely affect the results of operations.**

 

There are numerous hazards involved in the drilling and operation of oil and gas wells, including blowouts involving possible damages to property and third parties, bodily injuries, mechanical failures, explosions, uncontrollable flows of crude oil, natural gas or well fluids, fires, formations with abnormal pressure, pollution, releases of toxic gas and other environmental hazards and risks. The Partnership could suffer substantial losses as a result of any of these risks. The Partnership is not fully insured against all risks inherent to the oil and gas business. Uninsured liabilities would reduce the funds available to the Partnership, may result in the loss of Partnership properties and may create liability for the general partners. Although the Partnership maintains insurance coverage in amounts Reef deems appropriate, it is possible that insurance coverage may be insufficient. In that case Partnership assets may have to be sold to pay personal injury and property claims and the cost of controlling blowouts or replacing damaged equipment rather than for drilling activities.

 

**We cannot control activities on non-operated properties.**

 

The Partnership has limited ability to exercise influence over and control the risks associated with operations on properties not operated by RELP. The failure of an operator of our wells to adequately perform operations, an operator’s breach of the applicable agreements, or an operator’s failure to act in ways that are in our best interest could reduce our production and revenues. The success and timing of drilling and development activities on properties operated by others depends upon a number of factors outside of our control, including the operator’s

 
| · |   | timing and amount of capital expenditures;               |
|--------|--------|----------------------------------------------------------|
| · |   | expertise and financial resources;                       |
| · |   | inclusion of other participants in drilling wells;   and |
| · |   | use of technology.                                       |

 

In addition, the Partnership could be held liable for the joint interest obligations of other working interest owners, such as nonpayment of costs and liabilities arising from the actions of the other working interest owners. Full development of prospects may be jeopardized in the event other working interest owners cannot pay their share of drilling and completion costs.

 

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**Crude oil and natural gas reserve data are estimates based upon assumptions that may be inaccurate and existing economic and operating conditions that may differ from future economic and operating conditions.**

 

Securities and Exchange Commission (SEC) rules require the Partnership to present annual estimates of reserves. Reservoir engineering is a subjective process of estimating the recovery from underground accumulations of crude oil and natural gas that cannot be precisely measured, and is based upon assumptions that may vary considerably from actual results. Accordingly, reserve estimates may be subject to upward or downward adjustments. Actual production, revenues and expenditures with respect to reserves will likely vary from estimates, and such variances could be material.

 

You should not assume the present value of future net cash flows referred to in this Annual Report to be the current market value of our estimated crude oil and natural gas reserves. The estimated discounted future net cash flows from our proved reserves as of December 31, 2010 are based upon the 12-month unweighted arithmetic average of the first-day-of-the-month prices and costs in effect when the estimate is made. Actual current prices, as well as future prices and costs, may be materially higher or lower. Further, actual future net cash flows will be affected by factors such as the amount and timing of actual production, supply and demand for crude oil and natural gas, and changes in governmental regulations and tax rates.

 

**The Partnership Agreement limits Reef’s liability to each partner and the Partnership and requires the Partnership to indemnify Reef against certain losses.**

 

Reef will have no liability to the Partnership or to any partner for any loss suffered by the Partnership, and will be indemnified by the Partnership against loss sustained by it in connection with the Partnership if:

 
| · |   | Reef determines in good faith that its action was   in the best interest of the Partnership; |
|--------|--------|----------------------------------------------------------------------------------------------|
| · |   | Reef was acting on behalf of or performing   services for the Partnership; and               |
| · |   | Reef’s actions did not constitute negligence or   misconduct.                           |

 

**The production and producing life of Partnership wells is uncertain.**

 

Production will decline. It is not possible to predict the life and production of any well. The actual life could differ from that which is anticipated. Sufficient crude oil or natural gas may not be produced for a partner to receive a profit or even to recover his initial investment. In addition, production from the Partnership’s oil and gas wells, if any, will decline over time, and does not indicate any consistent level of future production. This production decline may be rapid and irregular when compared to a well’s initial production.

 

**Extreme weather conditions may adversely affect production operations and partner distributions.**

 

The Partnership conducts operations in the Gulf of Mexico and in coastal regions of Louisiana and Texas. This area is susceptible to extreme weather conditions, especially those associated with hurricanes. In the event of a hurricane and related storm activity, such as windstorms, storm surges, floods and tornados, Partnership operations in the region may be adversely affected. The occurrence of a hurricane or other extreme weather may harm or delay the Partnership’s operations or distribution of revenues, if any.

 

**Our dependence on third parties for the processing and transportation of crude oil and natural gas may adversely affect the Partnership’s revenues and, consequently, the distribution of net cash flows to investor partners*.***

 

We rely on third parties to process and transport the crude oil and natural gas produced by the Partnership’s successful wells. In the event a third party upon whom we rely is unable to provide transportation or processing services, and another third party is unavailable to provide such services, the Partnership may have to temporarily shut-in successful wells, and revenues to the Partnership and distributions to investor partners related to those wells may be delayed.

 

**We face strong competition within the energy industry.**

 

The oil and gas industry is highly competitive. Competition is encountered in all aspects of Partnership operations, including the requisition of drilling and service contractors. Many of our competitors are larger, well-established 

 

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companies with substantially larger operating staffs and greater capital resources than those of the Partnership, Reef and its affiliates. We may not be able to conduct our operations successfully, obtain drilling and service contractors, consummate transactions, and obtain technical, managerial and other professional personnel in this highly competitive environment. Specifically, larger competitors may be able to pay more for competent personnel than the Partnership, Reef and its affiliates. In addition, such competitors may be able to expend greater resources on the existing and changing technologies that will be increasingly important to success. Such competitors may also be in a better position to secure drilling and oilfield services, as well as equipment, more timely or on more favorable terms. Finally, oil and gas producers are increasingly facing competition from providers of non-fossil energy, and government policy may favor those competitors in the future.

 

**The Partnership has limited external sources of funds, which could result in a shortage of working capital.**

 

The Partnership expended funds in excess of the previously raised capital in connection with the drilling and completion of wells and acquisition of the prospects during the drilling phase of operations. These excess expenditures have been recovered through reductions in Partnership distributions.  The Partnership only has nominal funds available for Partnership purposes until there are revenues from Partnership operations. Any future requirement for additional funding for drilling will have to come, if at all, from the Partnership’s revenues or from borrowings. Reef cannot assure the partners that Partnership operations will be sufficient to provide the Partnership with necessary additional funding.  Reef cannot assure the partners that the Partnership will be able to borrow funds from third parties on commercially reasonable terms or at all.

 

**The Partnership may incur liability for liens against its subcontractors.**

 

Although Reef will try to determine the financial condition of nonaffiliated subcontractors, if subcontractors fail to timely pay for materials and services, the properties of the Partnership could be subject to materialmen’s and workmen’s liens.  In that event, the Partnership could incur excess costs in discharging such liens.

 

**Other partnerships Reef sponsors will compete with the Partnership for equipment, contractors, and personnel.**

 

Reef plans to offer interests in other partnerships to be formed for substantially the same purposes as those of the Partnership. Therefore, a number of partnerships with unexpended capital funds, including those partnerships to be formed in future oil and gas programs sponsored by Reef, may exist at the same time.  Due to competition among the partnerships for equipment, contractors, and Reef’s personnel, the fact that other partnerships organized by Reef and its affiliates may still be purchasing prospects and drilling and completing wells when the Partnership is attempting to drill and complete wells on its prospects may make such activities of the Partnership more difficult.

 

**ITEM 1B.                UNRESOLVED STAFF COMMENTS**

 

None.

 

**ITEM 2.                   PROPERTIES**

 

**Drilling Activities and Productive Wells**

 

Partnership prospects are located onshore in Texas, Louisiana, Oklahoma, and New Mexico and offshore in U.S. coastal waters in the Gulf of Mexico. The Partnership purchased working interests in twenty developmental prospects. The Partnership participated in drilling eight successful developmental wells on eight developmental prospects located in Acadia Parish, Louisiana, Pittsburg County, Oklahoma, and Palo Pinto, Jackson, Harris, Galveston, and Lavaca (2 prospects) County, Texas. One well located in Lavaca County, Texas ceased production during 2007, two wells located in Acadia Parish, Louisiana and Jackson County, Texas ceased production during 2008, and two wells located in Lavaca and Palo Pinto County, Texas ceased production during 2009. The Partnership sold its interest in two wells located in Pittsburg, Oklahoma and Palo Pinto County, Texas during 2010. One well located in Galveston, Texas was still producing as of December 31, 2010. The Partnership drilled eleven unsuccessful developmental wells on eleven developmental prospects located in West Baton Rouge, Acadia, Calcasieu, and Cameron Parish, Louisiana, and in Hardin, Upton, Ector, Jefferson, Lavaca, Reeves, and Dawson County, Texas.

 

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The Partnership participated in the drilling of eight developmental wells on the Sand Dunes prospect located in Eddy County, New Mexico during the fourth quarter of 2007 and the first quarter of 2008. Initial testing confirmed the presence of crude oil and natural gas in all eight wells. However, the field was temporarily shut-in because of the lack of electric service and because of the high cost of trucking offsite the salt water volumes associated with the production of the crude oil and natural gas from the wells. Electrical service to the eight Sand Dunes wells was connected in September 2008. Based upon initial testing, larger bottom hole pumps were placed below the well perforations in three of the wells and testing was resumed in late September 2008 to determine the three wells’ commercial productivity. Water continued to be trucked offsite, and RELP applied for and received a permit which would allow for the conversion of one of the existing eight Sand Dunes wells into a water disposal well. RELP also explored the possibility of drilling a ninth well as a salt water disposal well for the field. Testing results on two of the three wells were positive, and salt water production volumes declined as a result of pumping off the wells using the larger bottom hole pumps. However, the price of crude oil also declined at a rapid rate while testing was being conducted. In late December 2008, two of the three testing wells were shut-in again. Crude oil prices continued declining to a level below $40 per barrel. In February 2009, following a mechanical failure in the third testing well, RELP, as operator, shut-in the field. The eight wells could not be commercially productive without efficient salt water disposal capabilities, and none of the options regarding salt water disposal were economically viable at first quarter 2009 commodity prices. As a result, as of December 31, 2008, the eight Sand Dunes wells were classified as unsuccessful, and no crude oil and natural gas reserves for these wells were included in the December 31, 2008 reserve information presented in this Annual Report.

 

Beginning with March 2009, oil prices increased from levels below $40 per barrel to between $60 and $70 per barrel by the third quarter of 2009. As a result of this increase in prices, in October 2009, Reef approved the conversion of one of the eight wells on the Sand Dunes development prospect located in Eddy County, New Mexico to a salt water disposal well. The conversion work on the well began in March 2010 and was completed during April 2010.  Upon completion of the disposal facilities, the new disposal well became operational during August 2010. Based on the disposal capacity of the converted well, all of the remaining seven Sand Dunes wells have been placed into production as of December 31, 2010. The cost of the well conversion to this Partnership as of December 31, 2010 was approximately $172,355. This cost was paid for by the Partnership by retaining a portion of the funds normally paid out in distributions to the partners. There are 2,100 BBL of crude oil and 2,350 Mcf of natural gas reserves net to the Partnership’s interest for the wells placed on full time production during 2010.  As a result, the Sand Dunes wells have been classified as successful as of December 31, 2010.

 

The Partnership also has interests in unproved property consisting of un-drilled leasehold interests (11 potential drilling locations) in the Sand Dunes prospect. The Partnership fully impaired this unproved property during the fourth quarter of 2008 and has no plans to conduct any drilling operations on this acreage.

 

The Partnership purchased working interests in fourteen exploratory prospects, upon which a total of sixteen exploratory and eight developmental wells were drilled. The Partnership participated in drilling eight successful exploratory wells, one unsuccessful exploratory well, seven successful developmental wells, and one unsuccessful developmental well on seven exploratory prospects located in Terrebonne and St. Martin Parish, Louisiana, Sterling, Nueces (2 prospects) and Live Oak County, Texas, and offshore in U.S. Coastal waters in the Gulf of Mexico. The Partnership drilled seven unsuccessful exploratory wells on seven exploratory prospects located in West Baton Rouge, Beauregard, and Cameron Parish, Louisiana, Brazoria, Lavaca, and San Patricio County, Texas, and offshore in U.S. Coastal waters in the Gulf of Mexico. Of the fifteen successful wells, three wells located in St. Martin and Terrebonne Parish, Louisiana and in Live Oak County, Texas ceased production in 2006 and 2007 and one well in the Gulf of Mexico ceased production in 2010.

 

Twenty of the thirty-one successful wells in which the Partnership participated in drilling are currently active, of which nineteen are producing and one has been converted into a salt water disposal well.

 

**Proved Crude Oil and Natural Gas Reserves**

 

In January 2009, the SEC adopted new rules related to modernizing reserve calculation and disclosure requirements for oil and gas companies, which became effective prospectively for annual reporting periods ending on or after December 31, 2009.  In addition to expanding the definition and disclosure requirements for crude oil and natural

 

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gas reserves, the new rule changes the requirements for determining quantities of crude oil and natural gas reserves. The new rule requires disclosure of crude oil and natural gas proved reserves by significant geographic area, using the unweighted arithmetic average of first-day-of-the-month commodity prices over the preceding 12-month period, rather than end-of-period prices, and allows the use of reliable technologies to estimate proved crude oil and natural gas reserves, if those technologies have been demonstrated to result in reliable conclusions about reserves volumes. Reserve and related information for 2010 and 2009 is presented consistent with the requirements of the new rule. The new rule does not allow prior-year reserve information to be restated, so all information related to periods prior to December 31, 2009 is presented consistent with prior SEC rules for the estimation of proved reserves. The effect of applying the new definition of reliable technology and other non-price related aspects of the updated rules did not significantly impact 2009 net proved reserve volumes.  All of the Partnership’s reserves are located in the United States.

 

The estimated net proved crude oil and natural gas reserves at December 31, 2010, 2009, and 2008 are summarized below. The estimated quantities of proved crude oil and natural gas reserves discussed in this section include only the amounts which the Partnership reasonably expects to recover in the future from known oil and gas reservoirs under the current economic and operating conditions. Proved reserves include only quantities that the Partnership expects to recover commercially using current prices, costs, existing regulatory practices, and technology. Therefore, any changes in future prices, costs, regulations, technology or other unforeseen factors could materially increase or decrease the proved reserve estimates.

 
| ** **                                  | ** ** | **Oil (BBL)** | ** ** | **Gas (MCF)** | ** ** |
|---------------------------------------------|------------|--------------------|------------|--------------------|------------|
| Net proved reserves, December 31, 2008 |       | 99,980             |       | 2,232,028          |       |
| Net proved reserves, December 31, 2009 |       | 55,630             |       | 748,590            |       |
| Net proved reserves, December 31, 2010 |       | 48,860             |       | 792,380            |       |

 

The standardized measure of discounted future net cash flows as of December 31, 2010 and 2009 is computed by applying the 12-month average beginning-of-month price for the year, costs, and legislated tax rates and a discount factor of 10% to net proved reserves.  The standardized measure of discounted future net cash flows as of December 31, 2008 is computed by applying year-end prices, costs, and legislated tax rates and a discount factor of 10% to net proved reserves. The standardized measure of discounted future net cash flows does not purport to present the fair value of our crude oil and natural gas reserves.

 
| Standardized measure of discounted future net cash   flows as of December 31, 2008 |   | $ | 10,651,949 |   |
|-----------------------------------------------------------------------------------------|--------|---|------------|--------|
| Standardized measure of discounted future net cash   flows as of December 31, 2009 |   | $ | 3,600,860  |   |
| Standardized measure of discounted future net cash   flows as of December 31, 2010 |   | $ | 4,890,110  |   |

 

During the years ended December 31, 2010, 2009, and 2008, the Partnership recorded property impairment costs of proved properties totaling $0, $4,629,688, and $0 as a result of the net capitalized costs of proved oil and gas properties exceeding the sum of estimated future net revenues from proved reserves, using the methodologies described above.

 

**Qualifications of Technical Persons and Internal Controls Over the Reserves Estimation Process**

 

The Partnership used an independent petroleum consulting company, Forrest A. Garb & Associates, Inc., (“FGA”) of Dallas, Texas, to prepare its December 31, 2010 and 2009 estimates of net proved crude oil and natural gas reserves.  FGA estimated reserves for all of our properties as of December 31, 2010 and 2009. The technical personnel responsible for preparing the reserve estimates at FGA meet the requirements regarding qualifications, independence, objectivity, and confidentiality set forth in the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers. FGA is an independent firm of petroleum engineers and geologists. They do not own an interest in any of our properties, and are not employed on a contingent fee basis. FGA’s report was developed utilizing state reporting records and published production data purchased from third parties, and data provided by Reef.  Their reserve summary, which contains further

 

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discussions of the reserve estimates and evaluations, as well as the qualifications of FGA’s technical personnel responsible for overseeing their estimates and evaluations, is included as Exhibit 99.1 to this Annual Report.

 

The Partnership used an independent petroleum engineer, Gleason Engineering, of Arlington, Texas, to prepare its December 31, 2008 estimates of net proved crude oil and natural gas reserves.

 

Reef’s policies and practices regarding internal controls over the recording of reserves are structured to objectively and accurately estimate oil and gas reserve quantities and present values in compliance with SEC regulations and US Generally Accepted Accounting Principles (“GAAP”).

 

Reef maintains a staff of technical personnel who are well versed in the engineering evaluation computer programs and technology used and who provide well and production data to our independent petroleum engineering firm, FGA. Our accounting department accumulates historical production and pricing data and lease operating expenses for our wells, as well as the percentage interest owned by the Partnership, which is reviewed by our technical staff. Reserve estimates are prepared by FGA. Our technical staff and members of our accounting department meet regularly with FGA’s representatives to review properties and discuss methods and assumptions used in the preparation of their estimates. Mr. H. Walt Dunagin, Executive Vice President, Land Manager — Acquisitions and Divestitures for RELP, is the senior executive of RELP primarily responsible for overseeing the preparation of reserve estimates by FGA. Mr. Dunagin is a Professional Landman with over thirty years of industry experience in oil and gas operations, acquisitions and divestitures. He is an active member of the American Association of Petroleum Landmen (“AAPL”) and the Association of International Petroleum Negotiators (“AIPN”). Any significant reserve changes are approved by Mr. Dunagin and Mr. Michael J. Mauceli, Chief Executive Officer of RELP.

 

**Title to Properties**

 

The Partnership’s interests in producing and non-producing acreage are in the form of assigned direct interests in leases held by the Partnership or by Reef on behalf of the Partnership. Such properties are subject to customary royalty interests and could be subject to liens incident to operating agreements, liens for current taxes and overriding royalty interests and other burdens.  The Partnership believes that none of these burdens will materially interfere with the use of such properties in the operation of the Partnership’s business and that it has or will obtain satisfactory title to all of its leases. Title will be held by the Partnership or by Reef on behalf of the Partnership.

 
| **ITEM 3.** | ** ** | **LEGAL PROCEEDINGS** | ** ** |
|-------------|------------|-----------------------|------------|

 

On August 26, 2010, Frank Stevenson (“Stevenson”) filed a lawsuit, styled *Stevenson v. Wayne Kirk, Michael J. Mauceli, Reef Global Energy Ventures II*, et al., Cause No. 10-10647, in the 191st Judicial District Court, Dallas County, Texas. The suit also names as defendants Reef Global Energy VI, L.P. and multiple other Reef-sponsored ventures and limited partnerships, as well as Reef Securities, Inc., among others.  On September 22, 2010, James and Carol Estle (the “Estles”) and Nancy Dykes Thurmond Antolic (“Antolic”) joined the suit as additional plaintiffs. On January 27, 2011, Donna Stevenson (Frank Stevenson’s spouse) and Jaimie Davis (“Davis”) joined the suit as additional plaintiffs. With respect to Davis’s claims, specifically, Reef Securities, Inc. did not offer or sell the interests in the Reef program that Davis purchased. Rather, she purchased her interests through an unaffiliated broker/dealer. In the First Amended Petition, plaintiffs alleged that, collectively, they were seeking in excess of $1 million in compensatory damages as well as exemplary damages, attorneys’ fees, pre- and post-judgment interest, and costs.  In the Second Amended Petition, plaintiffs seek an undisclosed, unspecified amount of damages. Plaintiffs assert claims of fraud, rescission under the Texas Securities Act, control person liability under the Texas Securities Act, and breach of fiduciary duty. Plaintiff Davis asserts against defendant Reef Oil & Gas Income and Development Fund, L.P. a claim for tortious interference with an existing contract.  Defendants believe plaintiffs’ claims are meritless, and with respect to many of the Reef programs named in the petition, defendants believe that the claims for fraud are barred by limitations, as are any claims for rescission or breach of fiduciary duty with respect to those programs. In addition, with respect to all Reef programs in which plaintiffs participated, each plaintiff received offering documents that thoroughly disclosed all material facts and risks associated with participation in such programs, particularly the fact that no guarantees or promises could be made or relied upon.

 

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Defendants (including Reef Global Energy VI, L.P.) intend to vigorously defend the lawsuit and may seek damages from plaintiffs based upon, among other things, breaches of representations and warranties made by them as well as the indemnification provisions of the documents executed by each of them. As of this time, no substantive discovery has been conducted, and no trial date has been set.

** **
| **ITEM 4.** | ** ** | **(Removed   and Reserved)** |
|-------------|------------|------------------------------|

** **

**PART II**

** **
| **ITEM 5.** | ** ** | **MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND   ISSUER PURCHASES OF EQUITY SECURITIES** |
|------------------|------------|-------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|

 

As of December 31, 2010, the Partnership had one managing general partner, and 1,150 non-Reef investor partners (“investor partners”). Pursuant to the Partnership Agreement of the Partnership, all general partner units held by investor partners were converted into limited partner units during the 3rd quarter of 2008. Reef holds a total of 75.363 general partner units and the investor partners hold 1,431.897 limited partner units. No established trading market exists for the units.

 

Cash which, in the sole judgment of the managing general partner, is not required to meet the Partnership’s obligations is distributed to the partners at least quarterly in accordance with the Partnership Agreement. The Partnership has made monthly cash distributions to the partners of interest income and crude oil and natural gas sales revenues, less operating, general and administrative, and other costs since December 2005.  Cash distributions are distributed 15.45% to the managing general partner (based upon the 11% interest not represented by units and the 4.45% interest represented by Partnership units) and 84.55% to investor partners.

 

Investor limited partner interests are transferable, subject to certain restrictions contained in the Partnership Agreement; however, no assignee of a unit in the Partnership can become a substituted partner without the written consent of both the transferor and Reef.

 

The Partnership has adopted a unit repurchase program. Under the terms of the program, the managing general partner is obligated to purchase up to 5% of the units in the Partnership per year during the period set forth in the Partnership Agreement, unless changes in oil and gas pricing meet certain criteria specified in the prospectus supplement, dated July 8, 2005. However, the managing general partner’s obligation to purchase units is limited to $500,000 per year in the aggregate for all partnerships previously or subsequently organized by the managing general partner or its affiliates. The Partnership did not repurchase any units in 2010.

 

**Use of Proceeds**

 

In connection with the Registration Statement filed on form S-1 (No. 333-122935) and declared effective July 7, 2005, Reef filed a final prospectus for the Program on July 8, 2005. On July 8, 2005, Reef filed a prospectus supplement describing the Partnership and commenced the offering of units in the Partnership. All sales of Partnership units were made through the Program’s dealer-manager, Reef Securities, Inc., and a number of soliciting dealers. The offering terminated October 31, 2005. Under the terms of the offering, a minimum of 40 Partnership units at a price of $25,000 per unit were required to be sold in order to form the Partnership. Upon meeting this requirement, the Partnership was formed on July 18, 2005.

 

The Partnership registered a total of 400 units of limited partner interests and 1,600 units of general partner interests. The aggregate offering amount registered was $50,000,000. During the offering period that terminated on October 31, 2005, the Partnership sold 1,431.897 units to investor partners, consisting of 241.336 units of limited partner interest and 1,190.561 units of additional general partner interest. Reef purchased 75.363 general partner units, equaling 5.00% of the total Partnership units sold. The Partnership did not sell the remaining registered units. Total offering proceeds were $37,398,898. Reef also contributes 1% of all leasehold, drilling, and completion costs as incurred. At December 31, 2010, Reef had contributed $316,361 in connection with this obligation.

 

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All units except those purchased by Reef paid a 15% management fee to Reef to pay for the Partnership organization and offering costs, including sales commissions. These costs totaled $5,369,615, leaving capital contributions of $32,345,644 available for Partnership oil and gas operations. The Partnership expended $33,101,838 on the drilling of 49 wells and $138,317 on general and administrative expenses during its initial drilling phase of operations. The Partnership also expended $306,940 on the drilling of a successful exploratory well in September 2008 and an unsuccessful exploratory well in March 2009, subsequent to the completion of the Partnership’s drilling phase. Expenditures in excess of capital contributions were deducted from Partnership distributions.

 
| **ITEM 6.** |   | **SELECTED FINANCIAL DATA** |
|-------------|--------|-----------------------------|

 

The following table sets forth selected financial data. The selected financial data presented below has been derived from the audited financial statements of the Partnership.

 
| ** **                                      | ** ** | **As of and For the Years Ended December 31,** | ** ** |
|-------------------------------------------------|------------|----------------------------------------------------------------------------------------|------------|
| ** **                                      | ** ** | **2010**                                                                               | ** ** | **2009** | ** ** | **2008** | ** ** | **2007** | ** ** | **2006** | ** ** |
|                                            |       |                                                                                   |       |   |   |   |   |   |   |   |   |
| Revenue                                         |       | $                                                                                      | 4,427,215  |   | $ | 4,719,395 |   | $ | 9,444,159 |   | $ | 4,211,670 |   | $ | 552,572 |   |
| Interest income                                 |       | 607                                                                                    |       | 3,086 |   | 15,179 |   | 387,479 |   | 836,045 |   |
| Costs and expenses                              |       | (3,238,699                                                                             | )          | (8,628,475 | ) | (5,011,335 | ) | (12,887,713 | ) | (8,877,529 | ) |
| Net income (loss)                               |       | 1,189,123                                                                              |       | (3,905,994 | ) | 4,448,003 |   | (8,288,564 | ) | (7,488,912 | ) |
|                                            |       |                                                                                   |       |   |   |   |   |   |   |   |   |
| Allocation of net income (loss):                |       |                                                                                   |       |   |   |   |   |   |   |   |   |
| Managing general partner                        |       | 342,841                                                                                |       | 54,109 |   | 920,577 |   | (156,552 | ) | (331,615 | ) |
| General partner units                           |       | —                                                                                 |       | — |   | 1,875,514 |   | (6,761,418 | ) | (5,950,984 | ) |
| Limited partner units                           |       | 846,282                                                                                |       | (3,960,103 | ) | 1,651,912 |   | (1,370,594 | ) | (1,206,313 | ) |
| Net income (loss) per managing partner unit     |       | 4,549.20                                                                               |       | 717.98 |   | 12,215.24 |   | (2,077.31 | ) | (4,400.24 | ) |
| Net income (loss) per general partner unit      |       | —                                                                                 |       | — |   | 1,575.32 |   | (5,679.19 | ) | (4,998.47 | ) |
| Net income (loss) per limited partner unit      |       | 591.02                                                                                 |       | (2,765.63 | ) | 2,463.46 |   | (5,679.19 | ) | (4,998.47 | ) |
|                                            |       |                                                                                   |       |   |   |   |   |   |   |   |   |
| Total assets                                    |       | 2,815,422                                                                              |       | 4,520,645 |   | 11,539,478 |   | 13,913,337 |   | 28,061,160 |   |
| Distributions to managing general partner       |       | 481,675                                                                                |       | 475,948 |   | 966,629 |   | 453,728 |   | 142,700 |   |
| Distributions to investor partners              |       | 2,635,960                                                                              |       | 2,604,624 |   | 5,289,871 |   | 2,483,022 |   | 780,923 |   |
| Distributions per general partner unit          |       | —                                                                                 |       | — |   | 1,719.76 |   | 1,734.08 |   | 545.38 |   |
| Distributions per limited partner unit          |       | 1,840.89                                                                               |       | 1,819.00 |   | 3,694.31 |   | 1,734.08 |   | 545.38 |   |
| Distributions per managing general partner unit |       | 6,391.40                                                                               |       | 6,315.41 |   | 12,826.31 |   | 6,020.57 |   | 1,893.50 |   |
|                                            |       |                                                                                   |       |   |   |   |   |   |   |   |   |
| **Operating Data**                              |       |                                                                                   |       |   |   |   |   |   |   |   |   |
| Annual sales volume:                            |       |                                                                                   |       |   |   |   |   |   |   |   |   |
| Gas (MCF)                                       |       | 399,549                                                                                |       | 685,360 |   | 659,300 |   | 373,949 |   | 69,088 |   |
| Oil (BBL)                                       |       | 34,584                                                                                 |       | 37,439 |   | 33,086 |   | 20,002 |   | 2,374 |   |
|                                            |       |                                                                                   |       |   |   |   |   |   |   |   |   |
| Average sales price:                            |       |                                                                                   |       |   |   |   |   |   |   |   |   |
| Gas (per MCF)                                   |       | $                                                                                      | 5.05       |   | $ | 4.00 |   | $ | 9.36 |   | $ | 7.29 |   | $ | 5.99 |   |
| Oil (per BBL)                                   |       | $                                                                                      | 69.71      |   | $ | 52.83 |   | $ | 98.92 |   | $ | 74.20 |   | $ | 58.37 |   |

 

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| **ITEM 7.** |   | **MANAGEMENT’S   DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS** |
|-------------|--------|--------------------------------------------------------------------------------------------------|

 

The following discussion will assist you in understanding the Partnership’s financial position, liquidity, and results of operations. The information should be read in conjunction with the audited financial statements and notes to financial statements contained herein. The discussion contains historical and forward-looking information.

 

For a discussion of risk factors that could impact the Partnership’s financial results, please see Item 1A of this Annual Report.

 

**Critical Accounting Policies**

 

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires us to make estimates and assumptions that can affect the reporting of assets, liabilities, equity, revenues, and expenses. We base our estimates on historical experience and various other assumptions that are believed to be reasonable under the circumstances. Actual results may differ from these estimates under different assumptions or conditions. We are also required to select among alternative acceptable accounting policies. See Note 2 to the financial statements for a complete list of significant accounting policies.

 

**Oil and Gas Properties**

 

The Partnership follows the full cost method of accounting for oil and gas properties. Under this method, all direct costs and certain indirect costs associated with acquisition of properties and successful as well as unsuccessful exploration and development activities are capitalized. Depreciation, depletion, and amortization of capitalized oil and gas properties and estimated future development costs, excluding unproved properties, are based on the unit-of-production method using estimated proved reserves.  For these purposes, proved natural gas reserves are converted to equivalent barrels of crude oil at a rate of 6 Mcf to 1 Bbl.

 

In applying the full cost method at December 31, 2010, we perform a quarterly ceiling test on the capitalized costs of oil and gas properties, whereby the capitalized costs of oil and gas properties are limited to the sum of the estimated future net revenues from proved reserves using prices that are the 12-month unweighted arithmetic average of the first-day-of-the-month price for crude oil and natural gas held constant and discounted at 10%, plus the lower of cost or estimated fair value of  unproved properties, if any, for 2010. If capitalized costs exceed the ceiling, an impairment loss is recognized for the amount by which the capitalized costs exceed the ceiling, and is shown as a reduction of oil and gas properties and as property impairment expense on the Partnership’s statement of operations.  No gain or loss is recognized upon sale or disposition of oil and gas properties, unless such a sale would significantly alter the rate of depletion and amortization. During the years ended December 31, 2010, 2009, and 2008, the Partnership recognized property impairment expense of proved properties totaling $0, $4,629,688, and $0, respectively.

 

Unproved properties consist of undeveloped leasehold interest. Investments in unproved properties are not depleted pending determination of the existence of proved reserves. Unproved properties are assessed for impairment quarterly as of the balance sheet date by considering the primary lease term, the holding period of the properties, geologic data obtained relating to the properties, and other drilling activity in the immediate area of the properties. Any impairment resulting from this quarterly assessment is reported as property impairment expense in the current period, as appropriate. During the year ended December 31, 2008, the Partnership fully impaired its unproved properties by recognizing $172,930 of property impairment expense.

 

The estimate of proved crude oil and natural gas reserves used to determine property impairment expense, and also utilized in the Partnership’s disclosures of supplemental information regarding oil and gas producing activities, including the standardized measure of discounted cash flows, was prepared by an independent petroleum engineer at  December 31, 2010, 2009, and 2008, utilizing prices and costs as promulgated by the SEC. Reservoir engineering is a subjective and inexact process of estimating underground accumulations of crude oil and natural gas that cannot be

 

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measured in an exact manner, and is based upon assumptions that may vary considerably from actual results. Accordingly, reserve estimates may be subject to upward or downward adjustments. Actual production, revenues and expenditures with respect to reserves will likely vary from estimates, and such variances could be material.

 

The determination of depreciation, depletion and amortization expense recognized in the financial statements is also dependent upon the estimates of proved crude oil and natural gas reserves and is computed using the units-of-production method based upon this estimate of proved reserves. During the years ended December 31, 2010, 2009, and 2008, the Partnership had depreciation, depletion, and amortization expense totaling $1,725,156, $2,343,937, and $2,320,505, respectively.

 

Asset retirement costs and liabilities associated with future site restoration and abandonment of long-lived assets are initially measured at fair value which approximates the cost a third party would incur in performing the tasks necessary to retire such assets. The fair value is recognized in the financial statements as the present value of expected future cash expenditures for site restoration and abandonment. Subsequent to the initial measurement, the effect of the passage of time on the liability for the net asset retirement obligation (accretion expense) and the amortization of the asset retirement cost are recognized in the results of operations.

 

The following table summarizes the Partnership’s asset retirement obligation for the years ended December 31, 2010 and 2009.

 
| ** **                                                   | ** ** | **2010** | ** ** | **2009**   | ** ** |
|--------------------------------------------------------------|------------|----------|------------|------------|------------|
| Beginning asset retirement obligation                        | ** ** | **$**    | 393,393    | ** ** | **$**      | 386,346 | ** ** |
| Additions related to well conversion                         |       | 5,478    |       | —     |       |
| Accretion expense                                            |       | 68,979   |       | 22,310     |       |
| Retirement related to property sale                          |       | (873     | )          | —     |       |
| Retirement related to property abandonment and   restoration |       | (37,150  | )          | (15,263    | )          |
| Ending asset retirement obligation                           | ** ** | **$**    | 429,827    | ** ** | **$**      | 393,393 | ** ** |

 

**Recognition of Revenue**

 

The Partnership has entered into sales contracts for disposition of its share of crude oil and natural gas production from productive wells. Revenue is recognized based upon the metered volumes delivered to those purchasers each month. Any significant over or under balanced gas positions are disclosed in the financial statements. As of December 31, 2010, 2009 and 2008, the Partnership had no material gas imbalance positions.

 

**Recently Adopted Accounting Pronouncements**

 

**Modernization of Oil and Gas Reporting**

 

In January 2009, the SEC adopted a new rule related to modernizing reserve calculation and disclosure requirements for oil and gas companies, which became effective prospectively for annual reporting periods ending on or after December 31, 2009. In addition to expanding the definition and disclosure requirements for crude oil and natural gas reserves, the new rule changes the requirements for determining quantities of crude oil and natural gas reserves. The new rule requires disclosure of crude oil and natural gas proved reserves by geographical area, using the unweighted arithmetic average of first-day-of-the-month commodity prices over the preceding 12-month period, rather than end-of-period prices, and allows the use of reliable technologies to estimate proved crude oil and natural gas reserves, if those technologies have been demonstrated to result in reliable conclusions about reserve volumes.  In addition, in January 2010, the Financial Accounting Standards Board (“FASB”) issued guidance relating to crude oil and natural gas reserve estimation and disclosures to provide consistency with the new SEC rules.  The Partnership adopted the new standards effective December 31, 2009.  The new standards are applied prospectively as a change in estimate. In April 2010, the FASB issued a further accounting standards update regarding extractive oil and gas industries to incorporate in accounting standards the revisions to Rule 4-10 of the SEC’s Regulation S-X. The amendment primarily consists of the addition and deletion of definitions of terms related to fossil fuel exploration and production arising from technology changes over the past several decades. The accounting guidance in Rule 4-10 did not change.

 

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** **

**Overview**

 

Reef Global Energy VI, L.P. is a Nevada limited partnership formed to acquire, explore, develop, and produce crude oil, natural gas, and natural gas liquids for the benefit of its investor partners. The Partnership’s primary purposes are to generate revenues from the production of crude oil and natural gas, distribute cash flow to investors, and provide tax benefits to investors. The majority of the Partnership’s proceeds have been used to purchase prospects and drill oil and gas wells upon those prospects.

 

The Partnership raised capital from the sale of Partnership units to investor partners and Reef, and used those funds for the purchase of working interests in prospects and for drilling and completion operations and administrative costs during its drilling phase of operations. The Partnership did not borrow funds during the drilling phase of operations, and interest income and crude oil and natural gas revenues from successful wells, net of expenses, are being distributed monthly to the partners. The Partnership is allowed to borrow funds in accordance with the Partnership Agreement, or utilize cash flows from successful wells in order to conduct further development upon prospects initially purchased by and drilled on by the Partnership during the drilling phase of operations. The Partnership completed its drilling phase of operations during the first quarter of 2008. Subsequent to the original drilling phase of operations, the Partnership drilled two additional exploratory wells on one of the Partnerships’ prospects located in Live Oak County, Texas. An exploratory well drilled during the third quarter of 2008 was successful and began production operations in November of 2008. A second exploratory well drilled during March 2009 was unsuccessful and was plugged and abandoned. The Partnership utilized cash flow from existing wells by reducing distributions to partners in the drilling of these two wells. The Partnership may conduct additional drilling operations on its prospects in the future.

 

The Partnership does not operate in any other industry segment. The Partnership expended approximately $1,644,000 for the purchase of working interests in twenty developmental prospects, and expended approximately $1,237,000 for the purchase of working interests in fourteen exploratory prospects.  The Partnership has twenty prospects in Texas, ten in Louisiana, one in Oklahoma, and one in New Mexico, all of which are located onshore, and two prospects located offshore in U.S. coastal waters in the Gulf of Mexico. The Partnership has participated in drilling thirty-five developmental and sixteen exploratory wells on these prospects as of December 31, 2010. Forty-nine of these wells were drilled during the Partnership’s drilling phase of operations, and two additional wells were drilled subsequent to the completion of the Partnership’s drilling phase of operations.  Four wells were drilled during 2005, twenty-seven were drilled during 2006, fourteen were drilled during 2007, five were drilled during 2008, and one was drilled during 2009. The Partnership has participated in drilling twenty-three successful developmental wells, of which fifteen are currently producing and one has been converted to a salt water disposal well. The Partnership drilled twelve unsuccessful developmental wells. The Partnership drilled eight successful exploratory wells, of which four are currently producing. The Partnership drilled eight unsuccessful exploratory wells.

 

Should the Partnership elect to borrow monies for additional development activity on its prospects, it will be subject to the interest rate risk inherent in borrowing activities. The Partnership is permitted but is not expected to engage in commodity futures trading or hedging activities, and therefore is subject to commodity price risk.   See “Item 7A - Quantitative And Qualitative Disclosure About Market Risk.”

 

**Liquidity and Capital Resources**

 

The Partnership was funded with initial capital contributions totaling $37,398,898. Investor partners purchased 1,190.561 general partner units and 241.336 limited partner units for $35,797,434. Reef purchased 75.363 general partner units, or 5% of the total units sold, for $1,601,464. As of December 31, 2010, Reef has also contributed $316,361 in connection with its obligation to pay 1% of all leasehold, drilling, and completion costs. Organization and offering costs totaled $5,369,615, leaving capital contributions of $32,345,644 available for Partnership activities. The Partnership was formed on July 18, 2005, and the last partner was admitted to the Partnership on October 31, 2005.

 

The Partnership did not borrow additional funds in accordance with limitations set forth in the Partnership Agreement during the drilling phase of operations. The Partnership expended $33,101,838 on the drilling of 49 wells and $138,317 on general and administrative expenses during its initial drilling phase of operations. The Partnership also expended $306,940 on the drilling of a successful exploratory well in September 2008 and an unsuccessful

 

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exploratory well in March 2009, subsequent to the completion of the Partnership’s drilling phase. Expenditures in excess of capital contributions were deducted from Partnership distributions. There are no plans to conduct any additional drilling on Partnership prospects at this time; however, additional drilling activity is permitted on the Partnership prospects.

 

Please see Item 1A of this Annual Report for a list of risk factors that could impact the Partnership. The Partnership distributes to investors on at least a quarterly basis the net cash flow from interest income and crude oil and natural gas sales revenues from successful wells, less operating, general and administrative, and other costs.

 

The Partnership had working capital of $526,934 at December 31, 2010. Subsequent to expending the initial available Partnership capital contributions on prospect acquisitions and drilling and completion costs of partnership wells, the Partnership working capital consists primarily of cash flows from productive properties utilized to pay cash distributions to investors.

 

**Results of Operations**

 

**Year Ended December 31, 2010 compared to Year Ended December 31, 2009**

 

The Partnership had net income totaling $1,189,123 during 2010, compared to a net loss totaling $3,905,994 during 2009. The increase in operating results is due primarily to impairment taken during 2009. The Partnership had impairment of proved properties of $4,629,688 and no impairment of unproved properties during 2009, compared to no impairment of proved or unproved properties during 2010.

 

Due to rising commodity prices during the year, no impairment of properties was necessary during 2010. Impairment of proved properties totaling $2,417,333 occurred during the first quarter of 2009, and was the result of significant declines in commodity prices during that period. The decline in commodity prices resulted in shorter estimated economic lives for Partnership properties, which decreased both reserve estimates and the corresponding future net revenues expected from Partnership properties.   The estimated discounted future net cash flows of the Partnership totaled $7,251,567 at March 31, 2009, compared to $10,651,949 at December 31, 2008.  The Partnership took additional impairment of proved properties of $709,017 during the third quarter of 2009, due to the continuing decline in commodity prices. The Partnership took another significant impairment of proved properties of $1,503,338 during the fourth quarter of 2009, due to the effect of applying the new rules regarding reserve calculation and disclosures. See “Item 7 — Management’s Discussion and Analysis of Financial Condition and Results of Operations — Recently Adopted Accounting Pronouncements — Modernization of Oil and Gas Reporting” for more information regarding the new rules.

 

At December 31, 2010, the estimated discounted future net cash flows of the Partnership totaled $4,890,110, compared to $3,600,860 at December 31, 2009. This increase is primarily due to higher base sales prices at December 31, 2010, which impacts the estimated economic life of Partnership wells and estimated economic reserves to be produced from Partnership wells.

 

Gas sales volumes declined 41.7% during the year ended December 31, 2010 compared to the year ended December 31, 2009, and oil sales volumes declined by 7.6%. The HBR A well experienced a 54.9% decline in gas volumes and a 60.9% decline in oil volumes from 2009 production levels. The Dolphin B well ceased production in the first quarter of 2010, and therefore had no production during the last three quarters of 2010. The Dolphin B well had been one of the three most significant wells in which the Partnership had an interest. The Partnership’s share of sales volumes from its three major wells, the Dolphin B, the Gumbo II and the HBR A, totaled 32,161 barrels of crude oil and 296,114 Mcf of natural gas, or 93.0% and 74.1%, respectively, of the Partnership’s volumes during the year ended December 31, 2010. During the year ended December 31, 2009, the Partnership’s share of volumes from these three wells totaled 32,641 barrels of crude oil and 542,345 Mcf of natural gas, or 87.2% and 79.1%, respectively, of the Partnership’s volumes.  Sales prices for crude oil rose by 32.0%, to an average price of $69.71 during the year ended December 31, 2010. Sales prices for natural gas rose by 26.3% to an average price of $5.05 per Mcf, compared to an average price of $4.00 received during the year ended December 31, 2009. The increase in average prices was not enough to offset the decline in volumes, and total sales revenues decreased by 6.2% during the year ended December 31, 2010. The Partnership’s remaining two most significant wells as of December 31, 2010 accounted for 81.8% of Partnership crude oil and natural gas revenues during the year, and these two wells

 

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account for 73.1% of total Partnership reserves at December 31, 2010.

 

Lease operating costs decreased from $692,033 during the year ended December 31, 2009 to $434,104 during the year ended December 31, 2010. Expenses related to the Dolphin B, Ewald #1, and Long Ranch 73 #4 wells decreased by approximately $91,000 in total between the comparable periods.  These three wells were all plugged and abandoned or awaiting plugging and abandonment by the fourth quarter of 2009.  Lease operating costs for the Gumbo II well decreased by approximately $76,000 during the year ended December 31, 2010 compared to the year ended December 31, 2009.  Gas marketing expenses have also decreased in conjunction with declining gas volumes. Lease operating costs for the HBR A well decreased by $21,000 in conjunction with declining production and due to decreased ad valorem taxes during the year ended December 31, 2010.  Similarly, decreased ad valorem taxes related to the Sugg Ranch wells accounted for another decrease of $31,000 during the year ended December 31, 2010.

 

Production taxes decreased during the year ended December 31, 2010 compared to the year ended December 31, 2009 due to an approximate $174,000 adjustment received from the operator of the Gumbo II well.  In April 2010, the operator refunded prior production tax payments because the well obtained a severance tax exemption from the state of Louisiana for the period from inception through February 2010. This was a one time tax adjustment.

 

General and administrative costs increased from $664,555 incurred during the year ended December 31, 2009 to $902,057 incurred during the year ended December 31, 2010. Legal fees increased by approximately $360,000 as the Partnership reimbursed Reef for legal fees incurred to settle a lawsuit during the year ended December 31, 2010. Increased legal fees were offset by decreased overhead charges from RELP. Since the beginning of the second quarter of 2009, RELP has gradually reduced its total overhead costs by approximately 25%, and as such, the total overhead charged to partnerships has decreased in 2010 from 2009 levels. The allocation of RELP’s overhead to partnerships is based upon several factors, including the level of drilling activity, revenues, and capital and operating expenditures of each partnership compared to the total levels of all partnerships. Overall activity of this Partnership has begun to increase since the Sand Dunes wells began to be placed back on line during the third quarter of 2010, and accordingly, overhead charged by RELP increased during the third and fourth quarters of 2010 compared to the second quarter.  Despite this increase due to Sand Dunes, total overhead declined overall in 2010 from 2009 levels. The administrative overhead charge to the Partnership decreased from $529,185 for the year ended December 31, 2009 to $396,546 for the year ended December 31, 2010.

 

**Year Ended December 31, 2009 compared to Year Ended December 31, 2008**

 

The Partnership had a net loss totaling $3,905,994 during 2009, compared to net income totaling $4,448,003 during 2008. The decline in operating results is due to two primary factors. First, the Partnership saw significant decreases in the 2009 average sales prices for its crude oil of 46.6% and natural gas of 57.3% compared to 2008. Second, the Partnership had impairment of proved properties of $4,629,688 and no impairment of unproved properties during 2009, compared to no impairment of proved properties and $172,930 impairment of unproved properties during 2008.

 

Impairment of proved properties totaling $2,417,333 occurred during the first quarter of 2009, and was the result of significant declines in commodity prices. The decline in commodity prices resulted in shorter estimated economic lives for Partnership properties, which decreased both reserve estimates and the corresponding future net revenues expected from Partnership properties.   The estimated discounted future net cash flows of the Partnership totaled $7,251,567 at March 31, 2009, compared to $10,651,949 at December 31, 2008.  The Partnership took additional impairment of proved properties of $709,017 during the third quarter of 2009, due to the continuing decline in commodity prices. The Partnership took another significant impairment of proved properties of $1,503,338 during the fourth quarter of 2009, due to the effect of applying the new rules regarding reserve calculation and disclosures. See “Item 7 — Management’s Discussion and Analysis of Financial Condition and Results of Operations — Recently Adopted Accounting Pronouncements — Modernization of Oil and Gas Reporting” for more information regarding the new rules.

 

At December 31, 2009, the estimated discounted future net cash flows of the Partnership totaled $3,600,860, compared to $10,651,949 at December 31, 2008. Approximately $3.7 million of the reduction is the direct result of lower base sales prices at December 31, 2009, which impacts the estimated economic life of Partnership wells and

 

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estimated economic reserves to be produced from Partnership wells. The base year end prices for natural gas used in the Partnership’s reserve studies were $3.83 per MCF of natural gas at December 31, 2009, compared to $5.71 per MCF of natural gas at December 31, 2008. The prices used at December 31, 2009 reflect the new rules regarding reserve calculation, in which the prices are based on the unweighted arithmetic average of the first-day-of-the-month commodity prices over the preceding 12-month period and current costs, compared to the end-of-period commodity prices and costs as used in previous years.  See “Item 7 — Management’s Discussion and Analysis of Financial Condition and Results of Operations — Recently Adopted Accounting Pronouncements — Modernization of Oil and Gas Reporting” for more information regarding the new rules. As approximately 69.2% of the Partnership’s estimated proved reserves at December 31, 2009 were natural gas, financial results are sensitive to fluctuations in natural gas prices.  See “Item 7A — Quantitative and Qualitative Disclosure About Market Risk.” As such, the Partnership recorded impairment of proved properties during 2009 of $4,629,688.

 

During 2009, two Partnership wells accounted for 73.3% of Partnership crude oil and natural gas sales revenues, and these two wells account for 65.0% of total Partnership reserves at December 31, 2009.

 

Production expenses decreased during 2009 primarily due to decreases in sales prices. As a result of the decrease in sales prices received during 2009 as compared to 2008, production taxes decreased by $350,251 during 2009.

 

General and administrative costs decreased from $1,012,874 incurred during the year ended December 31, 2008 to $664,555 incurred during the year ended December 31, 2009, primarily due to decreased legal fees and decreased overhead charges. Effective April 1, 2008 Reef implemented a new method for allocating overhead that takes actual overhead and allocates it based upon the summation of revenues, expenses, and actual capital costs incurred. The administrative overhead charge to the Partnership decreased from $856,371 for the year ended December 31, 2008 to $529,185 for the year ended December 31, 2009.

 

**Off-Balance Sheet Arrangements**

 

The Partnership does not participate in transactions that generate relationships with unconsolidated entities or financial partnerships, such as entities often referred to as structure finance or special purpose entities (SPEs), which would have been established for the purpose of facilitating off-balance sheet arrangements or other contractually narrow or limited purposes.  As of December 31, 2010 and 2009, the Partnership was not involved in any unconsolidated SPE transactions or any other off-balance sheet arrangements.

 

**Contractual Obligations Table**

 

The Partnership has no obligations under non-cancelable agreements as of December 31, 2010.

** **
| **ITEM   7A.** |   | **QUANTITATIVE AND QUALITATIVE   DISCLOSURE ABOUT MARKET RISK** |
|----------------|--------|-----------------------------------------------------------------|

** **

**Interest Rate Risk**

 

The Partnership has not borrowed any funds to date. The Partnership Agreement allows borrowings from banks or other financial sources of up to 25% of the aggregate capital contributions to the Partnership without investor approval, provided the lender agrees it will have no recourse against individual investor partners, and allows borrowings in excess of 25% of the aggregate capital contributions to the Partnership with the consent of investor partners. Should the Partnership elect to borrow monies for additional drilling activity on Partnership prospects, it will be subject to the interest rate risk inherent in borrowing activities. Changes in interest rates could significantly affect the Partnership’s results of operations and the amount of net cash flow available for partner distributions. Also, to the extent that changes in interest rates affect general economic conditions, the Partnership will be affected by such changes.

 

**Commodity Price Risk**

 

The Partnership has not and does not expect to engage in commodity futures trading or hedging activities or enter into derivative financial instrument transactions for trading or other speculative purposes.  The Partnership sells a

 

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vast majority of its production from successful oil and gas wells on a month-to-month basis at current spot market prices. Accordingly, the Partnership is at risk for the volatility in commodity prices inherent in the oil and gas industry, and the level of commodity prices has a significant impact on the Partnership’s results of operations.

 

Assuming the production levels we attained during the year ended December 31, 2010, a 10% change in the price received for our crude oil would have had an approximate $241,082 impact on our crude oil revenues, and a 10% change in the price received for our natural gas would have had an approximate $201,772 impact on our natural gas revenues.

** **
| **ITEM 8.** | **FINANCIAL STATEMENTS AND   SUPPLEMENTARY DATA** |
|-------------|---------------------------------------------------|

 

The report of our independent registered public accounting firm, and the Partnership’s financial statements, related notes, and supplementary data are presented beginning on page F-1.

** **
| **ITEM 9.** | **CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING   AND FINANCIAL DISCLOSURE** |
|-------------|--------------------------------------------------------------------------------------------|

 

None.

 
| **ITEM 9A.** | **CONTROLS AND PROCEDURES** |
|--------------|-----------------------------|

 

**Evaluation of Disclosure Controls and Procedures**

 

As the managing general partner of the Partnership, Reef maintains a system of controls and procedures designed to provide reasonable assurance as to the reliability of the financial statements and other disclosures included in this Annual Report, as well as to safeguard assets from unauthorized use or disposition. The Partnership, under the supervision and with participation of its management, including the principal executive officer and principal financial and accounting officer of the Partnership’s managing general partner, Reef Oil & Gas Partners, L.P., evaluated the effectiveness of its “disclosure controls and procedures” as such term is defined in Rule 13a-15(e) under the Securities Exchange Act of 1934, as amended (the Exchange Act), as of the end of the period covered by this Annual Report. Based on that evaluation,  the principal executive officer and principal financial and accounting officer of our managing general partner have concluded that the Partnership’s disclosure controls and procedures are effective to ensure that information required to be disclosed by the Partnership in reports that it files or submits under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in Securities and Exchange Commission rules and forms, and includes controls and procedures designed to ensure that information required to be disclosed by us in such reports is accumulated and communicated to our management, including the principal executive officer and principal financial and accounting officer of our managing general partner, as appropriate to allow timely decisions regarding financial disclosure.

 

**Management Report on Internal Control Over Financial Reporting**

 

Management of the Partnership is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rule 13a-15(f). Our management conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on this evaluation under the framework in Internal Control - Integrated Framework, management of the Partnership concluded that the Partnership’s internal control over financial reporting was effective as of December 31, 2010.

 

This annual report does not include an attestation report of the Partnership’s independent registered public accounting firm regarding internal control over financial reporting. Management’s report was not subject to attestation by the Partnership’s registered public accounting firm pursuant to rules of the SEC that permit the Partnership to provide only management’s report in this annual report.

 

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**Changes in Internal Controls**

 

There have not been any changes in the Partnership’s internal controls over financial reporting during the fiscal quarter ended December 31, 2010 that have materially affected, or are reasonably likely to materially affect, the Partnership’s internal control over financial reporting.

** **
| **ITEM 9B.** | **OTHER INFORMATION** |
|--------------|-----------------------|

 

None.

 

**PART III**

** **
| **ITEM 10.** | **DIRECTORS, EXECUTIVE OFFICERS,   AND CORPORATE GOVERNANCE** |
|--------------|---------------------------------------------------------------|

 

The Partnership has no directors or executive officers. Its managing general partner is Reef Oil & Gas Partners, L.P.

 

**Reef Oil & Gas Partners, L.P. and Reef Exploration, L.P.**

 

The Manager, officers and key personnel of the managing general partner, their ages, current positions with the managing general partner and/or RELP, and certain additional information are set forth below.

 
| **Name**             | ** ** | **Age** | ** ** | **Positions and Offices Held**                                          |
|----------------------|------------|---------|------------|----------------------------------------------------------------------------------------|
| Michael   J. Mauceli |       | 54      |       | Manager   of Reef Oil & Gas Partners GP, LLC; Chief Executive Officer of RELP |
| H.   Walt Dunagin    |       | 53      |       | Executive   Vice President and Land Manager of RELP                                    |
| Daniel   C. Sibley   |       | 59      |       | Chief   Financial Officer and General Counsel of RELP                                  |
| David   M. Tierney   |       | 58      |       | Chief   Financial Reporting Officer and Treasurer of RELP                              |

 

**Michael J. Mauceli** is the Manager and a member of Reef Oil & Gas Partners, GP, LLC, which is the general partner of Reef, as well as the Chief Executive Officer of RELP. Mr. Mauceli has been the principal executive officer of Reef since its formation in February 1999. He has served in this position with RELP since January 2006 and has served in this position with its predecessor entity, OREI, Inc. (OREI) since 1987.  Mr. Mauceli attended the University of Mississippi where he majored in business management and marketing as well as the University of Houston where he received his Commercial Real Estate License. He entered the oil and natural gas business in 1976 when he joined Tenneco Oil & Gas Company.  Mr. Mauceli moved to Dallas in 1979, where he was independently employed by several exploration and development firms in planning exploration and marketing feasibility of privately sponsored drilling programs.

 

**H. Walt Dunagin** is Executive Vice President and Land Manager of RELP. He has held this position since January 2006 and has served in this position with its predecessor entity, OREI, since 1990. He is responsible for all contracts with other industry partners and all land activities required for exploration, development and production, including lease acquisition, title opinions, curative, permitting, unitization, rights-of-way and environmental issues. A graduate of the University of Mississippi in 1969 with a B.B.A. degree, Walt’s career has also involved land work for ExxonMobil, ChevronTexaco, UNOCAL, Santa Fe Energy and Oryx Energy (now Kerr-McGee). Walt is a member of the Dallas Association of Petroleum Landmen, the Association of International Petroleum Negotiators, and the American Association of Professional Landmen.

 

**Daniel C. Sibley**became Chief Financial Officer of RELP in March 2010 and General Counsel of RELP in January 2009.  He previously served as Chief Financial Officer of Reef from December 1999 until his appointment to General Counsel of RELP. He also served as Chief Financial Officer for RELP from January 2006 until his appointment to General Counsel of RELP, and had served in this same position with RELP’s predecessor entity, OREI, since 1998. Mr. Sibley was employed as a Certified Public Accountant with Grant Thornton from 1977 to 1980. From 1980 to 1994, he was involved in the private practice of law. He received a B.B.A. in accounting from the University of North Texas in 1973, a law degree (J.D.) from the University of Texas in 1977, and a Master of

 

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Laws-Taxation degree (L.L.M.) from Southern Methodist University in 1984.  Mr. Sibley became a certified public accountant in 1977, but no longer maintains this license.

 

**David M. Tierney**, the Chief Financial Reporting Officer and Treasurer of RELP, has been employed by RELP since January 2006 and was previously with its predecessor entity, OREI, Inc., since March 2001.  Mr. Tierney became Chief Financial Reporting Officer of RELP in March 2010 and Treasurer of RELP in May 2009.  Prior to that, Mr. Tierney served as Chief Accounting Officer — Public Partnerships of RELP starting in July 2008. From 2001 to 2008, Mr. Tierney was the Controller of the Reef Global Energy Ventures and Reef Global Energy Ventures II partnerships.  Mr. Tierney received a Bachelor’s degree from Davidson College in 1974, a Masters of Business Administration from Tulane University in 1976, and is a Texas Certified Public Accountant.  Mr. Tierney has worked in public accounting, and has worked in the oil and gas industry since 1979.  From 1992 through 2000 he served as controller/treasurer of an independent oil and gas exploration company.

 

On May 29, 2009, Reef SWD 2007-A, L.P. (“Reef SWD 2007-A”), an affiliate of Reef,filed a lawsuit against Ricardo Guevara and certain of his affiliates alleging that Guevara misrepresented and omitted material information in regard to Reef SWD 2007-A’s purchase of four salt water disposal facilities located in Webb and Zapata Counties, Texas for a price of $7.5 million.  The lawsuit, styled Reef SWD 2007-A v. Ricardo Guevara, et al. (Cause No. 09-06828) was filed in the 14th-A Judicial District Court of Dallas County, Texas and sought rescission and actual damages, consequential damages, exemplary damages, attorneys’ fees, and costs.  On October 1, 2009, the court entered an order transferring the venue of the case to Zapata County, Texas.  On January 4, 2010, Reef SWD 2007-A non-suited Mr. Guevara and his affiliates and terminated its Texas state court litigation against them.  On January 5, 2010, Reef SWD 2007-A instituted a federal bankruptcy Chapter 11 proceeding in the U.S. Bankruptcy Court for the Northern District of Texas.  As part of that proceeding, Reef SWD 2007-A is asserting claims against Mr. Guevara and his affiliates similar in nature to the claims that were brought in the Texas state courts, as well as certain claims regarding fraudulent conveyances, which can only be brought in bankruptcy court.  On March 30, 2010, Reef SWD 2007-A filed an application with the court to convert the Chapter 11 proceeding to a Chapter 7 proceeding under the U.S. Bankruptcy Code. Pursuant to those proceedings, Reef SWD 2007-A sold all of its operating assets for approximately $1.3 million dollars. On November 3, 2010, Mr. Guevara et al. filed a counterclaim against Reef SWD 2007-A in the bankruptcy matter, alleging breach of contract for unpaid amounts allegedly due under the note from Reef SWD 2007-A (related to the original, underlying transaction) and tort claims of fraud, negligent misrepresentation, negligence, gross negligence, and breach of fiduciary duty.  On February 23, 2011, the court dismissed with prejudice in part the tort claims asserted by Defendants.  The court gave Defendants until March 15, 2011 to file an amended counterclaim relating to alleged fraud concerning Reef SWD 2007-A’s prior experience with saltwater disposal facilities but no amended counterclaim was filed. The case is presently set for trial during the week of October 17, 2011. Reef SWD 2007-A still intends to vigorously pursue its claims against Mr. Guevara and his affiliates and to defend any remaining counterclaims.

 

**Audit Committee and Nominating Committee**

 

Because the Partnership has no directors, it does not have an audit committee, an audit committee financial expert or a nominating committee.

 

**Code of Ethics**

 

Because the Partnership has no employees, it does not have a code of ethics.  Employees of the Partnership’s managing general partner, Reef, must comply with Reef’s Code of Ethics, a copy of which will be provided to investor partners, without charge, upon request made to Reef Oil & Gas Partners, L.P., 1901 N. Central Expressway, Suite 300, Richardson, Texas 75080, Attention: Daniel C. Sibley.

 
| **ITEM 11.** | **EXECUTIVE COMPENSATION** |
|--------------|----------------------------|

 

The following table summarizes the items of compensation to be received by Reef as the managing general partner from the Partnership.

 

24

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| **Recipient**                               | ** ** | **Form of Compensation**                                                                    | ** ** | **Amount**                   |
|---------------------------------------------|------------|-------------------------------------------------------------------------------------------------------|------------|------------------------------|
| Managing   General Partner                  |       | Partnership interest (excluding any partnership   interest resulting from the purchase of units) |       | 10%   interest               |
| Managing   General Partner                  |       | Management   fee                                                                                      |       | 15%   of subscriptions       |
| Managing General Partner and its Affiliates |       | Direct   and administrative costs                                                                     |       | Reimbursement   at cost      |
| Affiliate   of the Managing General Partner |       | Operator’s   per-well charges                                                                    |       | Competitive   prices         |
| Managing General Partner and its Affiliates |       | Payment for equipment, supplies, marketing, and   other services                                      |       | Cost   or competitive prices |

 

Reef’s “partnership interest,” as described in the table above, refers only to its interest as managing general partner and does not include the interest Reef has as the result of its purchase of units in the Partnership, or the 1% interest Reef has as the result of its payment of 1% of all leasehold, drilling, and completion costs.  Reef purchased 5.00% of the outstanding Partnership units. Reef received a 10% interest as managing general partner of the Partnership and a 1% interest as a result of Reef’s payment of 1% of all leasehold, drilling, and completion costs for a total of an 11% interest.  This 11% interest is not represented by partnership units.  Reef has a total interest in the Partnership of 15.45%.

 

Reef is entitled to receive a management fee equal to 15% of the Partnership subscriptions exclusive of the units purchased by Reef. From this amount Reef pays all of the Partnership’s organization and offering costs, including sales commissions. The management fee is payable to Reef in two parts. Reef initially received an amount not to exceed 13.5% to cover actual sales commissions and actual organization and offering costs. The remainder of the management fee is paid to Reef from the net cash flow available for partner distributions, at a rate not to exceed $1 million per year. The total management fee owed Reef is $5,369,615. The Partnership recorded $5,319,615 of this amount as offering costs, and $50,000 as organization costs. Of this amount, $4,564,826 has been paid to Reef to cover actual sales commissions and organization and offering costs, and $804,789 has been paid to Reef from net cash flows of the Partnership.

 

Reef is reimbursed for direct costs and all documented out-of-pocket expenses incurred on behalf of the Partnership, including administrative costs. During the years ended December 31, 2010, 2009, and 2008, the Partnership reimbursed Reef $8,795, $1,004, and $126,680, respectively, for technical services costs which have been capitalized as project costs, and $414,611, $545,623, and $856,371, respectively, for administrative costs included as general and administrative expenses.

 

Operator fees are payable to RELP for the wells on the twelve prospects where RELP serves as operator.  RELP receives operator fees during the drilling and production phase of each well at the competitive rate in the geographical area where the well is located.  These fees are charged as a monthly fee per well as agreed to in an operating agreement signed by the Partnership and participating third party working interest owners in the well. During the years ended December 31, 2010, 2009, and 2008, the Partnership paid operator fees totaling $18,350, $17,235, and $14,105 to RELP. RELP serves as operator for twelve Partnership prospects upon which eleven successful wells, one of which has been converted to a salt water disposal well, and eight unsuccessful wells have been drilled.

 

**Compensation Committee**

 

Because the Partnership has no directors, it does not have a compensation committee.

 
| **ITEM   12.** | **SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND   MANAGEMENT AND RELATED STOCKHOLDER MATTERS** |
|----------------|------------------------------------------------------------------------------------------------------|

 

The following table sets forth information as of December 31, 2010 concerning all persons known by Reef to own beneficially more than 5% of the interests in the Partnership. Unless expressly indicated otherwise, each partner exercises sole voting and investment power with respect to the units beneficially owned.

 

25

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| **Person or Group**              | ** ** | **Number of Units   Beneficially   Owned** | ** ** | **Percent of Total   Partnership   Units   Outstanding** | ** ** | **Percentage of   Total   Partnership   Interests   Beneficially   Owned** | ** ** |
|--------------------------------------------|------------|------------------------------------------------------|------------|--------------------------------------------------------------------|------------|---------------------------------------------------------------------------------|------------|
| Reef Oil & Gas Partners, L.P. (1) |       | 75.363                                               |       | 5.00                                                               | %          | 4.45                                                                            | %          |
| Reef Oil & Gas Partners, L.P. (1) |       | —                                               |       | —                                                             |       | 11.00                                                                           | %          |

 

----

(1) Reef Oil & Gas Partners, L.P.’s address is 1901 N. Central Expressway, Suite 300, Richardson, Texas 75080.

 

The managing general partner received a 10% interest in the Partnership as compensation for forming the Partnership, and also holds a 1% interest in the Partnership as a result of paying 1% of all leasehold, drilling and completion costs. In addition to this 11% interest not represented by Partnership units, Reef purchased 5% of the 1,507.260 Partnership units and, therefore, holds 5% of the 89% interest in the Partnership (4.45%) held by the unit holders.

 
| **ITEM   13.** | **CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND   DIRECTOR INDEPENDENCE** |
|----------------|---------------------------------------------------------------------------------|

 

The Partnership is managed by a managing general partner and does not have directors. Reef is the managing general partner of the Partnership.  Along with its affiliates, Reef has entered into agreements with, and received compensation from, the Partnership for services it performs for the Partnership.  See “Item 11 - Executive Compensation.”

 
| **ITEM 14.** | **PRINCIPAL ACCOUNTANT FEES AND   SERVICES** |
|--------------|----------------------------------------------|

 

The Partnership incurred professional audit and tax fees from its principal auditor BDO USA, LLP, as disclosed in the table below:

 
| ** **         | ** ** | **2010** | ** ** | **2009** | ** ** |
|--------------------|------------|----------|------------|----------|------------|
| Audit fees         |       | $        | 52,968     |     | $          | 50,738 |   |
| Audit related fees |       | —   |       | —   |       |
| Tax fees           |       | —   |       | —   |       |
| All other fees     |       | —   |       | —   |       |
|                    |            |          |            |          |            |  |  |

 

As indicated in Item 10 above, the Partnership does not have any directors or an audit committee.

 

**PART IV**

 
| **ITEM 15.** | **EXHIBITS AND FINANCIAL STATEMENT SCHEDULES** |
|--------------|------------------------------------------------|

 
| (a)    | 1.   Financial Statements                                 |   |
|--------|-----------------------------------------------------------|--------|
|   |                                                      |   |
|   | Report of   Independent Registered Public Accounting Firm | F-1    |
|   | Balance Sheets                                            | F-2    |
|   | Statements of Operations                                  | F-3    |
|   | Statements of   Partnership Equity                        | F-4    |
|   | Statements of Cash Flows                                  | F-5    |
|   | Notes to   Financial Statements                           | F-6    |
|   |                                                      |   |
|   | 2.   Financial Statement Schedules                        | None   |
|   |                                                      |   |
|   | 3.   Exhibits                                             |   |

 

A list of the exhibits filed or furnished with this Annual Report (or incorporated by reference to exhibits previously filed or furnished by us) is provided in the Exhibit Index in this Annual Report.  Those exhibits incorporated by

 

26

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reference herein are indicated as such by the information supplied in the parenthetical thereafter. Otherwise, the exhibits are filed herewith.

 

**SIGNATURES**

 

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this Annual Report on Form 10-K to be signed on its behalf by the undersigned, thereunto duly authorized.

 

 
| Date:  March 31, 2011 | ** ** | **REEF   GLOBAL ENERGY VI, L.P.**                |
|---------------------------------|------------|--------------------------------------------------|
|                            |       |                                             |
|                            | By:        |  Reef Oil & Gas Partners, L.P.     |
|                            |       | Managing   General Partner                       |
|                            |       |                                             |
|                            |       |                                             |
|                            | By:        |  Reef Oil & Gas Partners, GP, LLC, |
|                            |       | its   general partner                            |
|                            |       |                                             |
|                            |       |                                             |
|                            | By:        | /s/   Michael J. Mauceli                         |
|                            |       |                                             | Michael   J. Mauceli |
|                            |       |                                             | Manager and Member |
|                            |       |                                             | (*Principal Executive   Officer*) |
|                                 |            |                                                  |  |  |

 

27

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Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.

 
| **Signature**          | ** ** | **Title**                                                                                                               | ** ** | **Date**            |
|------------------------|------------|-------------------------------------------------------------------------------------------------------------------------|------------|---------------------|
| ** **             | ** ** | ** **                                                                                                              | ** ** | ** **          |
| /s/ Michael J. Mauceli |       | Manager   and Member of Reef Oil & Gas Partners, GP,                                                           |       | March 31, 2011 |
| Michael J. Mauceli     |       | LLC,   the general partner of Reef Oil & Gas Partners,                                                         |       |                |
|                   |       | L.P.,   the Managing General Partner of the Partnership                                                                 |       |                |
|                   |       | (*Principal Executive Officer*)                                                                                         |       |                |
|                   |       |                                                                                                                    |       |                |
|                   |       |                                                                                                                    |       |                |
| /s/   Daniel C. Sibley |       | Chief   Financial Officer and General Counsel of Reef Exploration, L.P.

(*Principal Financial and Accounting Officer*) |       | March 31, 2011 |
| Daniel   C. Sibley     |       |                                                                                                                    |       |
|                   |       |                                                                                                                    |       |

 

28

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**EXHIBIT INDEX**

** **
| 3.1(a)(i)   |       | Certificate of Limited Partnership (incorporated by reference to Exhibit 3.1 to Form 8-A, SEC File No. 000-53539, as filed with the SEC on March 30, 2007).         |
|-------------|------------|--------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------|
| ** **  | ** ** | ** **                                                                                                                                                                                                                                                                                       |
| 3.1(a)(ii)  |       | Certificate of Amendment to the   Certificate of Limited Partnership of Reef Global Energy VI, L.P., dated   August 27, 2008 (incorporated by reference to   Exhibit 3.1(i)(a) to Form 8-K, SEC File No. 000-53539, as   filed with the SEC on September 3, 2008). |
| ** **  | ** ** | ** **                                                                                                                                                                                                                                                                                       |
| 3.1(a)(iii) |       | Certificate of Amendment to the   Certificate of Limited Partnership of Reef Global Energy VI, L.P., dated   August 28, 2008 (incorporated by reference to   Exhibit 3.1(i)(b) to Form 8-K, SEC File No. 000-53539, as   filed with the SEC on September 3, 2008). |
| ** **  | ** ** | ** **                                                                                                                                                                                                                                                                                       |
| 3.2         |       | Form of   Limited Partnership Agreement (incorporated by reference to Exhibit 3.1   to Form S-1, SEC file No.333-122935, as filed with the SEC on   June 24, 2005).                                                                                                          |
| ** **  | ** ** | ** **                                                                                                                                                                                                                                                                                       |
| 10.1        |       | Letter   Agreement, dated November 7, 2001, by and between Reef Partners LLC and   Challenger Minerals Inc. (incorporated by reference to Exhibit 10.2 of   the Annual Report on Form 10-K of Reef Global Energy Ventures as filed   with the SEC on March 5, 2002).         |
|        |       |                                                                                                                                                                                                                                                                                             |
| 23.2*       |       | Consent   of Forrest A. Garb & Associates, Inc.                                                                                                                                                                                                                                    |
| ** **  | ** ** | ** **                                                                                                                                                                                                                                                                                       |
| 31.1*       |       | Certification   of Principal Executive Officer pursuant to Rule 13a-14(a) under the   Securities Exchange Act of 1934.                                                                                                                                                                 |
| ** **  | ** ** | ** **                                                                                                                                                                                                                                                                                       |
| 31.2*       |       | Certification   of Principal Financial Officer pursuant to Rule 13a-14(a) under the   Securities Exchange Act of 1934.                                                                                                                                                                 |
| ** **  | ** ** | ** **                                                                                                                                                                                                                                                                                       |
| 32.1*       |       | Certification   of Principal Executive Officer pursuant to 18 U.S.C. §1350.                                                                                                                                                                                                                 |
| ** **  | ** ** | ** **                                                                                                                                                                                                                                                                                       |
| 32.2*       |       | Certification   of Principal Financial Officer pursuant to 18 U.S.C. §1350.                                                                                                                                                                                                                 |
|        |       |                                                                                                                                                                                                                                                                                             |
| 99.1*       |       | Summary   Reserve Report of Forrest A. Garb & Associates, Inc.                                                                                                                                                                                                                     |

 

----

|   |   | * Attached herewith |
|--------|--------|---------------------|

 

29

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Reef Global Energy VI, L.P.

 

Financial Statements

 

Years Ended December 31, 2010, 2009, and 2008

 

**Contents**

 
| Report   of Independent Registered Public Accounting Firm | F-1    |
|-----------------------------------------------------------|--------|
|                                                      |   |
| Audited   Financial Statements                            |   |
|                                                      |   |
| Balance sheets                                            | F-2    |
| Statements of   operations                                | F-3    |
| Statements   of partnership equity                        | F-4    |
| Statements of   cash flows                                | F-5    |
| Notes to   financial statements                           | F-6    |

 

30

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Report of Independent Registered Public Accounting Firm

 

The Partners

Reef Global Energy VI, L.P.

 

We have audited the accompanying balance sheets of Reef Global Energy VI, L.P. as of December 31, 2010 and 2009, and the related statements of operations, partnership equity, and cash flows for each of the three years in the period ended December 31, 2010. These financial statements are the responsibility of the Partnership’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

 

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Partnership is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. An audit includes consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Partnership’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

 

In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Reef Global Energy VI, L.P. at December 31, 2010 and 2009, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2010, in conformity with accounting principles generally accepted in the United States of America.

 

As discussed in Note 2 to the financial statements, effective December 31, 2009, the Partnership changed its reserve estimates and related disclosures as a result of adopting new oil and gas reserve estimation and disclosure requirements.

 
| /S/   BDO USA, LLP    |   |
|-----------------------|--------|
|                  |   |
|                  |   |
| Dallas,   Texas       |   |
| March 31,   2011 |   |

 

F-1

----

Table of Contents

 

**Reef Global Energy VI, L.P.**

**Balance Sheets**

 
| **December 31,**                                                            | ** ** | **2010**      | ** **    | **2009**      | ** ** |
|----------------------------------------------------------------------------------|------------|---------------|---------------|---------------|------------|
|                                                                             |       |          |          |          |       |
| **Assets**                                                                       |       |          |          |          |       |
|                                                                             |       |          |          |          |       |
| **Current assets:**                                                              |       |          |          |          |       |
| Cash and cash equivalents                                                        | ** ** | **$**         | 182,919       | ** **    | **$**      | 165,715 | ** ** |
| Accounts receivable                                                              |       | 2,895         |          | 22,680        |       |
| Accounts receivable from affiliates                                              |       | 631,006       |          | 731,390       |       |
| **Total current assets**                                                         | ** ** | **816,820**   | ** **    | **919,785**   | ** ** |
|                                                                             |       |          |          |          |       |
| **Oil and gas properties, full   cost method of accounting:**                    |       |          |          |          |       |
| Proved properties, net of accumulated depletion of   $31,598,214 and $29,938,389 |       | 1,998,602     |          | 3,600,860     |       |
| **Net oil and gas properties**                                                   | ** ** | **1,998,602** | ** **    | **3,600,860** | ** ** |
| ** **                                                                       | ** ** | ** **    | ** **    | ** **    | ** ** |
| **Total assets**                                                                 |       | $             | **2,815,422** |          | $          | **4,520,645** |   |
|                                                                             |       |          |          |          |       |
| **Liabilities and partnership   equity**                                         |       |          |          |          |       |
|                                                                             |       |          |          |          |       |
| **Current liabilities:**                                                         |       |          |          |          |       |
| Accounts payable                                                                 | ** ** | **$**         | 18,372        | ** **    | **$**      | 103,031 | ** ** |
| Accounts payable to affiliates                                                   |       | 271,514       |          | —        |       |
| **Total current liabilities**                                                    | ** ** | **289,886**   | ** **    | **103,031**   | ** ** |
|                                                                             |       |          |          |          |       |
| **Long-term liabilities:**                                                       |       |          |          |          |       |
| Asset retirement obligation                                                      |       | 429,827       |          | 393,393       |       |
| **Total long-term liabilities**                                                  | ** ** | **429,827**   | ** **    | **393,393**   | ** ** |
|                                                                             |       |          |          |          |       |
| **Commitments and contingencies   (Note 5)**                                     |       |          |          |          |       |
|                                                                             |       |          |          |          |       |
| **Partnership equity**                                                           |       |          |          |          |       |
| Limited partners                                                                 |       | 1,881,392     |          | 3,671,070     |       |
| Managing general partner                                                         |       | 214,317       |          | 353,151       |       |
| **Partnership equity**                                                           | ** ** | **2,095,709** | ** **    | **4,024,221** | ** ** |
| ** **                                                                       | ** ** | ** **    | ** **    | ** **    | ** ** |
| **Total liabilities and   partnership equity**                                   | ** ** | **$**         | **2,815,422** | ** **    | **$**      | **4,520,645** | ** ** |

 

*See accompanying notes to financial statements.*

 

F-2

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Table of Contents

 

**Reef Global Energy VI, L.P.**

**Statements of Operations**

 
| ** **                                   | ** ** | **For the Years Ended December 31,** | ** **    |
|----------------------------------------------|------------|---------------------------------------------------------------|---------------|
| ** **                                   | ** ** | **2010**                                                      | ** **    | **2009** | ** ** | **2008** | ** ** |
| ** **                                   | ** ** | ** **                                                    | ** **    | ** ** | ** ** | ** ** | ** ** |
| **Revenues**                                 | ** ** | **$**                                                         | **4,427,215** | ** ** | **$** | **4,719,395** | ** ** | **$** | **9,444,159** | ** ** |
| ** **                                   | ** ** | ** **                                                    | ** **    | ** ** | ** ** | ** ** | ** ** |
| **Costs and expenses:**                      | ** ** | ** **                                                    | ** **    | ** ** | ** ** | ** ** | ** ** |
| Lease operating expenses                     |       | 434,104                                                       |          | 692,033 |   | 818,037 |   |
| Production taxes                             |       | 108,403                                                       |          | 275,952 |   | 626,203 |   |
| Depreciation, depletion and amortization     |       | 1,725,156                                                     |          | 2,343,937 |   | 2,320,505 |   |
| Property impairment                          |       | —                                                        |          | 4,629,688 |   | 172,930 |   |
| Accretion of asset retirement obligation     |       | 68,979                                                        |          | 22,310 |   | 60,786 |   |
| General and administrative                   |       | 902,057                                                       |          | 664,555 |   | 1,012,874 |   |
| **Total costs and expenses**                 | ** ** | **3,238,699**                                                 | ** **    | **8,628,475** | ** ** | **5,011,335** | ** ** |
| ** **                                   | ** ** | ** **                                                    | ** **    | ** ** | ** ** | ** ** | ** ** |
| **Income (loss) from operations**            | ** ** | **1,188,516**                                                 | ** **    | **(3,909,080** | **)** | **4,432,824** | ** ** |
| ** **                                   | ** ** | ** **                                                    | ** **    | ** ** | ** ** | ** ** | ** ** |
| **Other income:**                            | ** ** | ** **                                                    | ** **    | ** ** | ** ** | ** ** | ** ** |
| Interest income                              |       | 607                                                           |          | 3,086 |   | 15,179 |   |
| ** **                                   | ** ** | ** **                                                    | ** **    | ** ** | ** ** | ** ** | ** ** |
| **Net income (loss)**                        | ** ** | **$**                                                         | **1,189,123** | ** ** | **$** | **(3,905,994** | **)** | **$** | **4,448,003** | ** ** |
| ** **                                   | ** ** | ** **                                                    | ** **    | ** ** | ** ** | ** ** | ** ** |
| Net income per general partner unit          | ** ** | **$**                                                         | **—**    | ** ** | **$** | **—** | ** ** | **$** | **1,575.32** | ** ** |
| Net income (loss) per limited partner unit   | ** ** | **$**                                                         | **591.02**    | ** ** | **$** | **(2,765.63** | **)** | **$** | **2,463.46** | ** ** |
| Net income per managing general partner unit | ** ** | **$**                                                         | **4,549.20**  | ** ** | **$** | **717.98** | ** ** | **$** | **12,215.24** | ** ** |

 

*See accompanying notes to financial statements.*

 

F-3

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Table of Contents

 

**Reef Global Energy VI, L.P.**

**Statements of Partnership Equity**

 
| ** **                                                                | ** ** | **General partners** | ** ** | **Limited partners** | ** ** | **Managing general partner** | ** ** | **Total**  | ** ** |
|---------------------------------------------------------------------------|------------|---------------------------|------------|---------------------------|------------|----------------------------------------|------------|------------|------------|
| ** **                                                                | ** ** | **Units**                 | ** ** | **Amount**                | ** ** | **Units**                              | ** ** | **Amount** | ** ** | **Units** | ** ** | **Amount** | ** ** | **Units** | ** ** | **Amount** | ** ** |
| Balance   at December 31, 2007                                       |       | 1,190.561                 |       | 9,975,966                 |       | 241.336                                |       | 2,022,276  |       | 75.363 |   | 801,418 |   | 1,507.260 |   | 12,799,660 |   |
| Partner   contributions                                                   |       | —                    |       | —                    |       | —                                 |       | —     |       | — |   | 12,019 |   | — |   | 12,019 |   |
| Partner   distributions                                                   |       | —                    |       | (2,047,479                | )          | —                                 |       | (3,242,392 | )          | — |   | (966,629 | ) | — |   | (6,256,500 | ) |
| Net   income                                                              |       | —                    |       | 1,875,514                 |       | —                                 |       | 1,651,912  |       | — |   | 920,577 |   | — |   | 4,448,003 |   |
| Conversion   of general partner units into limited partner units (Note 1) |       | (1,190.561                | )          | (9,804,001                | )          | 1,190.561                              |       | 9,804,001  |       | — |   | — |   | — |   | — |   |
| Balance   at December 31, 2008                                       |       | —                    |       | —                    |       | 1,431.897                              |       | 10,235,797 |       | 75.363 |   | 767,385 |   | 1,507.260 |   | 11,003,182 |   |
|                                                                      |       |                      |       |                      |       |                                   |       |       |       |   |   |   |   |   |   |   |   |
| Distribution   amount per partnership unit                                |       |                      |       | $                         | 1,719.76   |                                   |       |       | $          | 3,694.31 |   |   |   | $ | 12,826.31 |   |   |   |   |   |
|                                                                      |       |                      |       |                      |       |                                   |       |       |       |   |   |   |   |   |   |   |   |
| Balance   at December 31, 2008                                       |       | —                    |       | —                    |       | 1,431.897                              |       | 10,235,797 |       | 75.363 |   | 767,385 |   | 1,507.260 |   | 11,003,182 |   |
| Partner   contributions                                                   |       | —                    |       | —                    |       | —                                 |       | —     |       | — |   | 7,605 |   | — |   | 7,605 |   |
| Partner   distributions                                                   |       | —                    |       | —                    |       | —                                 |       | (2,604,624 | )          | — |   | (475,948 | ) | — |   | (3,080,572 | ) |
| Net   income (loss)                                                       |       | —                    |       | —                    |       | —                                 |       | (3,960,103 | )          | — |   | 54,109 |   | — |   | (3,905,994 | ) |
| Balance   at December 31, 2009                                       |       | —                    |       | $                         | —     |                                   | 1,431.897  |       | $          | 3,671,070 |   | 75.363 |   | $ | 353,151 |   | 1,507.260 |   | $ | 4,024,221 |   |
|                                                                      |       |                      |       |                      |       |                                   |       |       |       |   |   |   |   |   |   |   |   |
| Distribution   amount per partnership unit                                |       |                      |       | $                         | —     |                                   |       |       | $          | 1,819.00 |   |   |   | $ | 6,315.41 |   |   |   |   |   |
|                                                                      |       |                      |       |                      |       |                                   |       |       |       |   |   |   |   |   |   |   |   |
| Balance   at December 31, 2009                                       |       | —                    |       | —                    |       | 1,431.897                              |       | 3,671,070  |       | 75.363 |   | 353,151 |   | 1,507.260 |   | 4,024,221 |   |
| Partner   distributions                                                   |       | —                    |       | —                    |       | —                                 |       | (2,635,960 | )          | — |   | (481,675 | ) | — |   | (3,117,635 | ) |
| Net   income                                                              |       | —                    |       | —                    |       | —                                 |       | 846,282    |       | — |   | 342,841 |   | — |   | 1,189,123 |   |
| Balance   at December 31, 2010                                       |       | —                    |       | $                         | —     |                                   | 1,431.897  |       | $          | 1,881,392 |   | 75.363 |   | $ | 214,317 |   | 1,507.260 |   | $ | 2,095,709 |   |
|                                                                      |       |                      |       |                      |       |                                   |       |       |       |   |   |   |   |   |   |   |   |
| Distribution   amount per partnership unit                                |       |                      |       | $                         | —     |                                   |       |       | $          | 1,840.89 |   |   |   | $ | 6,391.40 |   |   |   |   |   |

 

*See accompanying notes to financial statements.*

 

F-4

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Table of Contents

 

**Reef Global Energy VI, L.P.**

**Statements of Cash Flows**

 
| ** **                                                                                 | ** ** | **For the Years Ended December 31,** | ** **  |
|--------------------------------------------------------------------------------------------|------------|---------------------------------------------------------------|-------------|
| ** **                                                                                 | ** ** | **2010**                                                      | ** **  | **2009** | ** ** | **2008** | ** ** |
| **Operating Activities**                                                                   |       |                                                          |        |   |   |   |   |
| Net income (loss)                                                                          |       | $                                                             | 1,189,123   |   | $ | (3,905,994 | ) | $ | 4,448,003 |   |
| Adjustments to reconcile net income (loss) to net   cash provided by operating activities: |       |                                                          |        |   |   |   |   |
| Plugging and abandonment costs paid from ARO                                               |       | (37,152                                                       | )           | (11,755 | ) | (7,008 | ) |
| ***Adjustments for non-cash   transactions:***                                             |       |                                                          |        |   |   |   |   |
| Depreciation, depletion and amortization                                                   |       | 1,725,156                                                     |        | 2,343,937 |   | 2,320,505 |   |
| Property impairment                                                                        |       | —                                                        |        | 4,629,688 |   | 172,930 |   |
| Accretion of asset retirement obligation                                                   |       | 68,979                                                        |        | 22,310 |   | 60,786 |   |
| ***Changes in operating assets and   liabilities:***                                       |       |                                                          |        |   |   |   |   |
| Accounts receivable                                                                        |       | 19,785                                                        |        | (20,000 | ) | (2,680 | ) |
| Accounts receivable from affiliates                                                        |       | 100,384                                                       |        | (586,904 | ) | (144,486 | ) |
| Accounts payable                                                                           |       | (84,659                                                       | )           | 97,870 |   | 3,180 |   |
| Accounts payable to affiliates                                                             |       | 271,514                                                       |        | — |   | — |   |
| **Net cash provided by operating   activities**                                            | ** ** | **3,253,130**                                                 | ** **  | **2,569,152** | ** ** | **6,851,230** | ** ** |
| ** **                                                                                 | ** ** | ** **                                                    | ** **  | ** ** | ** ** | ** ** | ** ** |
| **Investing Activities**                                                                   |       |                                                          |        |   |   |   |   |
| Proceeds from sale of property                                                             |       | 96,206                                                        |        | — |   | — |   |
| Property acquisition and development                                                       |       | (214,497                                                      | )           | (311,139 | ) | (1,262,454 | ) |
| **Net cash used in investing   activities**                                                | ** ** | **(118,291**                                                  | **)**       | **(311,139** | **)** | **(1,262,454** | **)** |
| ** **                                                                                 | ** ** | ** **                                                    | ** **  | ** ** | ** ** | ** ** | ** ** |
| **Financing Activities**                                                                   | ** ** | ** **                                                    | ** **  | ** ** | ** ** | ** ** | ** ** |
| Partner capital contributions                                                              |       | —                                                        |        | 7,605 |   | 27,117 |   |
| Offering costs                                                                             |       | —                                                        |        | (144,789 | ) | (600,000 | ) |
| Partner distributions                                                                      |       | (3,117,635                                                    | )           | (3,080,572 | ) | (6,256,500 | ) |
| **Net cash used in financing   activities**                                                | ** ** | **(3,117,635**                                                | **)**       | **(3,217,756** | **)** | **(6,829,383** | **)** |
| ** **                                                                                 | ** ** | ** **                                                    | ** **  | ** ** | ** ** | ** ** | ** ** |
| **Net increase (decrease) in cash   and cash equivalents**                                 | ** ** | **17,204**                                                    | ** **  | **(959,743** | **)** | **(1,240,607** | **)** |
| Cash and cash equivalents at beginning of period                                           |       | 165,715                                                       |        | 1,125,458 |   | 2,366,065 |   |
| **Cash and cash equivalents at   end of period**                                           | ** ** | **$**                                                         | **182,919** | ** ** | **$** | **165,715** | ** ** | **$** | **1,125,458** | ** ** |
| ** **                                                                                 | ** ** | ** **                                                    | ** **  | ** ** | ** ** | ** ** | ** ** |
| **Non-cash investing transactions**                                                        |       |                                                          |        |   |   |   |   |
| Property additions and asset retirement obligation                                         | ** ** | **$**                                                         | 5,478       |   | $ | — |   | $ | 35,166 |   |
| Adjustment to asset retirement obligation                                                  | ** ** | **$**                                                         | —      |   | $ | 3,508 |   | $ | 7,813 |   |
| **Non-cash financing   transactions:**                                                     | ** ** | ** **                                                    | ** **  | ** ** | ** ** | ** ** | ** ** |
| Offering costs included in accounts payable to   affiliates                                | ** ** | **$**                                                         | —      |   | $ | — |   | $ | 144,789 |   |

 

*See accompanying notes to financial statements.*

 

F-5

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Table of Contents

 

Reef Global Energy VI, L.P.

Notes to Financial Statements (continued)

 

**1. Organization and Basis of Presentation**

 

Reef Global Energy VI, L.P. (the “Partnership”) is the first in a series of four Nevada limited partnerships comprising a program called Reef Global Energy Ventures II (the “Program”), pursuant to an S-1 Registration Statement declared effective by the Securities and Exchange Commission (the “SEC”) on July 7, 2005. In order to be formed, each partnership was required to sell a minimum of 40 partnership units at $25,000 per unit, including units purchased by the managing general partner. Each partnership formed as a part of the program offered a minimum of 1,000 and a maximum of 2,000 units for sale. The Program was authorized to sell up to 1,600 limited partner units and 6,400 general partner units during the period beginning July 8, 2005 through July 7, 2007. The Partnership offered 2,000 units for sale ($50,000,000); consisting of up to 400 limited partner units and up to 1,600 general partner units. Investor funds were held in escrow and were subject to reimbursement with interest if the minimum number of units was not sold. The Program filed a prospectus supplement with the SEC on July 8, 2005 describing the Partnership, and commenced offering units in the Partnership. Upon reaching the minimum subscription level, the Partnership was formed on July 18, 2005. The Partnership offering closed October 31, 2005, with sales to outside investors totaling 1,190.561 general partner units and 241.336 limited partner units, and sales to the managing general partner totaling 75.363 general partner units.

 

The Partnership is a Nevada limited partnership formed under the Nevada Uniform Limited Partnership Act. Reef Oil & Gas Partners, L.P. (“Reef”) serves as the Partnership’s managing general partner. Partnership interests are held by the managing general partner and investor partners who are general and limited partners (“investor partners”). The managing general partner received a 10% interest in the Partnership as compensation for forming the Partnership, and also holds a 1% interest in the Partnership as a result of paying 1% of all leasehold, drilling and completion costs. This 11% interest is not represented by Partnership units. In addition, Reef purchased 5% of the Partnership units and, therefore, holds 5% of the 89% interest in the Partnership (4.45%) held by the unit holders. The Partnership purchased working interests in exploratory and developmental drilling prospects and drilled oil and gas wells located primarily onshore in the continental United States and in U.S. coastal waters in the Gulf of Mexico. Other partnerships formed as a part of this Program, as well as other partnerships managed by Reef, also own interests in some of the prospects purchased by this Partnership. In instances where Reef-affiliated entities own a majority working interest in a prospect, wells drilled on that prospect may be operated by Reef Exploration, L.P. (“RELP”), an affiliate of the managing general partner. The Partnership does not operate in any other industry segment.

 

Pursuant to the Partnership Agreement of the Partnership, all general partner units held by investors other than the managing general partner were converted into limited partner units. This conversion of general partner units into limited partner units occurred during the 3rd quarter of 2008. The general partner equity at June 30, 2008 was transferred to limited partner equity, and all income and expense items subsequent to the second quarter of 2008 were allocated between the managing general partner and the limited partners.

 

The Partnership has adopted a unit repurchase program. Under the terms of the program, the managing general partner is obligated to purchase up to 5% of the units in the Partnership per year during the period set forth in the Partnership Agreement, unless changes in oil and gas pricing meet certain criteria specified in the prospectus supplement, dated July 8, 2005. However, the managing general partner’s obligation to purchase units is limited to $500,000 per year in the aggregate for all partnerships previously or subsequently organized by the managing general partner or its affiliates. The Partnership did not repurchase any units in 2010.

 

Under the terms of the partnership agreement, certain income and expense items are allocated differently between the managing general partner and the investor partners.  Allocations of income and expense to the managing general partner and investor partners are made quarterly based upon the number and type of partnership units held at the end of the quarter.

 

Organization and offering costs are allocated 100% to investor partners, as the managing general partner purchases its units net of the 15% fee for organization and offering costs. Monthly cash distributions to partners are based upon the number and type of partnership units held at the close of the prior month. Cash distributions to partners of the net cash flow from interest income and crude oil and natural gas sales revenues, less operating, general and

 

F-6

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Table of Contents

 

Reef Global Energy VI, L.P.

Notes to Financial Statements (continued)

 

administrative, and other costs are distributed 15.45% to the managing general partner (based upon the 11% interest not represented by units and the 4.45% interest represented by Partnership units) and 84.55% to investor partners.

 

**2. Summary of Accounting Policies**

 

**Use of Estimates**

 

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. Actual results could differ from these estimates.

 

**Cash and Cash Equivalents**

 

The Partnership considers all highly liquid investments with maturity dates of no more than three months from the purchase date to be cash equivalents. Cash and cash equivalents consist of demand deposits and money market investments invested with a major national bank, which at times may exceed federally insured limits. The Partnership has not experienced any losses in such accounts, and does not expect any loss from this exposure. The carrying value of the Partnership’s cash equivalents approximates fair value.

 

**Risks and Uncertainties**

 

Historically, the oil and gas market has experienced significant price fluctuations. Prices are impacted by local weather, supply in the area, availability and price of competitive fuels, seasonal variations in local demand, limited transportation capacity to other regions, and the worldwide supply and demand balance for crude oil.

 

The Partnership has not engaged in commodity futures trading or hedging activities and has not entered into derivative financial instrument transactions for trading or other speculative purposes. Accordingly, the Partnership is at risk for the volatility in commodity prices inherent in the oil and gas industry, and the level of commodity prices has a significant impact on the Partnership’s results of operations.

 

**Oil and Gas Properties**

 

The Partnership follows the full cost method of accounting for oil and gas properties. Under this method, all direct costs and certain indirect costs associated with acquisition of properties and successful as well as unsuccessful exploration and development activities are capitalized. Depreciation, depletion, and amortization of capitalized oil and gas properties and estimated future development costs, excluding unproved properties, are based on the unit-of-production method using estimated proved reserves, as determined by independent petroleum engineers.  For these purposes, proved natural gas reserves are converted to equivalent barrels of crude oil at a rate of 6 Mcf to 1 Bbl.

 

In applying the full cost method at December 31, 2010, the Partnership performs a quarterly ceiling test on the capitalized costs of oil and gas properties, whereby the capitalized costs of oil and gas properties are limited to sum of the estimated future net revenues from proved reserves using prices that are the 12-month unweighted arithmetic average of the first-day-of-the-month price for crude oil and natural gas held constant and discounted at 10%, plus the lower of cost or estimated fair value of  unproved properties, if any, for 2010. If capitalized costs exceed the ceiling, an impairment loss is recognized for the amount by which the capitalized costs exceed the ceiling, and is shown as a reduction of oil and gas properties and as property impairment expense on the Partnership’s statement of operations.  No gain or loss is recognized upon sale or disposition of oil and gas properties, unless such a sale would significantly alter the rate of depletion and amortization. During the years ended December 31, 2010, 2009 and 2008, the Partnership recognized property impairment expense of proved properties totaling $0, $4,629,688, and $0, respectively.

 

Unproved properties consist of undeveloped leasehold interest. Investments in unproved properties are not depleted pending determination of the existence of proved reserves. Unproved properties are assessed for impairment quarterly as of the balance sheet date by considering the primary lease term, the holding period of the properties,

 

F-7

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Table of Contents

 

Reef Global Energy VI, L.P.

Notes to Financial Statements (continued)

 

geologic data obtained relating to the properties, and other drilling activity in the immediate area of the properties. Any impairment resulting from this quarterly assessment is reported as property impairment expense in the current period, as appropriate. During the year ended December 31, 2008, the Partnership fully impaired its unproved properties by recognizing $172,930, of property impairment expense.

 

**Estimates of Proved Oil and Gas Reserves**

 

Estimates of the Partnership’s proved reserves at December 31, 2010 and 2009 have been prepared and presented in accordance with new SEC rules and accounting standards. These new rules are effective for fiscal years ending on or after December 31, 2009, and require SEC reporting entities to prepare their reserve estimates using revised reserve definitions and revised pricing based upon the unweighted arithmetic average of the first-day-of-the-month commodity prices over the preceding 12 month period and current costs. Estimates of the Partnership’s proved reserves at December 31, 2008 have been prepared and presented using previous SEC rules and accounting standards that required pricing based upon end-of-period commodity prices and costs. Future prices and costs may be materially higher or lower than these prices and costs, which would impact the estimate of reserves and future cash flows. The Partnership’s proved reserve information included in this report was based upon evaluations prepared by independent petroleum engineers.

 

Reserves and their relation to estimated future net cash flows impact the Partnership’s depletion and impairment calculations. As a result, adjustments to depletion and impairment are made concurrently with changes to reserve estimates. If proved reserve estimates decline, the rate at which depletion expense is recorded increases, reducing net income. A decline in estimated proved reserves and future cash flows also reduces the capitalized cost ceiling and may result in increased impairment expense.

 

The adoption of the new SEC rules and accounting standards at December 31, 2009 resulted in a downward adjustment of $2,019,550 to the estimated discounted future cash flows from proved reserves, and in a reduction of 9,745 BOE equivalent of proved reserves. Additionally, the change resulted in increases of $15,483 and $1,503,338 in depletion and impairment expense, respectively, in the fourth quarter of 2009.

 

**Restoration, Removal, and Environmental Liabilities**

 

The Partnership is subject to extensive Federal, state and local environmental laws and regulations. These laws regulate the discharge of materials into the environment and may require the Partnership to remove or mitigate the environmental effects of the disposal or release of petroleum substances at various sites. Environmental expenditures are expensed or capitalized depending on their future economic benefit. Expenditures that relate to an existing condition caused by past operations and that have no future economic benefit are expensed.

 

Liabilities for expenditures of a non-capital nature are recorded when environmental assessments and/or remediation is probable, and the costs can be reasonably estimated. Such liabilities are generally undiscounted values unless the timing of cash payments for the liability or component is fixed or reliably determinable.

 

Asset retirement costs and liabilities associated with future site restoration and abandonment of long-lived assets are initially measured at fair value which approximates the cost a third party would incur in performing the tasks necessary to retire such assets. The fair value is recognized in the financial statements as the present value of expected future cash expenditures for site restoration and abandonment. Subsequent to the initial measurement, the effect of the passage of time on the liability for the net asset retirement obligation (accretion expense) and the amortization of the asset retirement cost are recognized in the results of operations.

 

The following table summarizes the Partnership’s asset retirement obligation for the years ended December 31, 2010 and 2009.

 
| ** **                                                   | ** ** | **2010** | ** ** | **2009**   | ** ** |
|--------------------------------------------------------------|------------|----------|------------|------------|------------|
| Beginning asset retirement obligation                        | ** ** | **$**    | 393,393    | ** ** | **$**      | 386,346 | ** ** |
| Additions related to well conversion                         |       | 5,478    |       | —     |       |
| Accretion expense                                            |       | 68,979   |       | 22,310     |       |
| Retirement related to property sale                          |       | (871     | )          | —     |       |
| Retirement related to property abandonment and   restoration |       | (37,152  | )          | (15,263    | )          |
| Ending asset retirement obligation                           | ** ** | **$**    | 429,827    | ** ** | **$**      | 393,393 | ** ** |

 

F-8

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Table of Contents

 

Reef Global Energy VI, L.P.

Notes to Financial Statements (continued)

 

**Recognition of Revenue**

 

The Partnership enters into sales contracts for disposition of its share of crude oil and natural gas production from productive wells. Revenues are recognized based upon the Partnership’s share of metered volumes delivered to its purchasers each month. The Partnership had no material gas imbalances at December 31, 2010, 2009, and 2008.

 

**Income Taxes**

 

The Partnership’s net income or loss flows directly through to its partners, who are responsible for the payment of Federal taxes on their respective share of any income or loss. Therefore, there is no provision for federal income taxes in the accompanying financial statements.

 

As of December 31, 2010, the tax basis of the Partnership’s assets exceeds the financial reporting basis of the assets by approximately $5.61 million, primarily due to the difference between property impairment costs deducted for financial reporting purposes and intangible drilling costs deducted for income tax purposes.

 

**Accounting for Uncertainty in Income Taxes**

 

FASB provides guidance on accounting for uncertainty in income taxes. This guidance is intended to clarify the accounting for uncertainty in income taxes recognized in a company’s financial statements and prescribes the recognition and measurement of a tax position taken or expected to be taken in a tax return. It also provides guidance on de-recognition, classification, interest and penalties, accounting in interim periods, disclosure and transition.

 

Under this guidance, evaluation of a tax position is a two-step process. The first step is to determine whether it is more-likely-than-not that a tax position will be sustained upon examination, including the resolution of any related appeals or litigation based on the technical merits of that position. The second step is to measure a tax position that meets the more-likely-than-not threshold to determine the amount of benefit to be recognized in the financial statements. A tax position is measured at the largest amount of benefit that is greater than 50% likely of being realized upon ultimate settlement.

 

Tax positions that previously failed to meet the more-likely-than-not recognition threshold should be recognized in the first subsequent period in which the threshold is met. Previously recognized tax positions that no longer meet the more-likely-than-not criteria should be de-recognized in the first subsequent reporting period in which the threshold is no longer met. Penalties and interest are classified as income tax expense.

 

Based on the Partnership’s assessment, there are no material uncertain tax positions as of December 31, 2010.

 

**Fair Value of Financial Instruments**

 

The estimated fair values for financial instruments have been determined at discrete points in time based on relevant market information. These estimates involve uncertainties and cannot be determined with precision. The estimated fair value of cash, accounts receivable, accounts receivable from affiliates, and accounts payable approximates their carrying value due to their short-term nature.

 

**Recently Adopted Accounting Pronouncements**

 

**Modernization of Oil and Gas Reporting**

 

In January 2009, the SEC adopted a new rule related to modernizing reserve calculation and disclosure requirements for oil and gas companies, which became effective prospectively for annual reporting periods ending on or after December 31, 2009. In addition to expanding the definition and disclosure requirements for crude oil and natural gas reserves, the new rule changes the requirements for determining quantities of crude oil and natural gas reserves. The

 

F-9

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Table of Contents

 

Reef Global Energy VI, L.P.

Notes to Financial Statements (continued)

 

new rule requires disclosure of crude oil and natural gas proved reserves by geographical area, using the unweighted arithmetic average of first-day-of-the-month commodity prices over the preceding 12-month period, rather than end-of-period prices, and allows the use of reliable technologies to estimate proved crude oil and natural gas reserves, if those technologies have been demonstrated to result in reliable conclusions about reserve volumes.  In addition, in January 2010, the Financial Accounting Standards Board (“FASB”) issued guidance relating to crude oil and natural gas reserve estimation and disclosures to provide consistency with the new SEC rules.  The Partnership adopted the new standards effective December 31, 2009.  The new standards are applied prospectively as a change in estimate. In April 2010, the FASB issued a further accounting standards update regarding extractive oil and gas industries to incorporate in accounting standards the revisions to Rule 4-10 of the SEC’s Regulation S-X. The amendment primarily consists of the addition and deletion of definitions of terms related to fossil fuel exploration and production arising from technology changes over the past several decades. The accounting guidance in Rule 4-10 did not change.

 

**3. Transactions with Affiliates**

 

The Partnership has no employees. RELP employs a staff including geologists, petroleum engineers, landmen and accounting personnel who administer all of the Partnership’s operations. The Partnership reimburses RELP for technical and administrative services at cost. During the years ended December 31, 2010, 2009, and 2008 the Partnership incurred technical services and administrative costs totaling $423,406, $546,627, and $983,051, respectively. Of these amounts $8,795, $1,004, and $126,680 represent technical services costs capitalized as project costs, and $414,611, $545,623, and $856,371 represent administrative costs included as general and administrative expenses.

 

Reef contributes 1% of all leasehold, drilling, and completion costs when incurred. During the years ended December 31, 2010 and 2009, this 1% obligation totaled $0 and $7,605, respectively. Reef also purchased 5% of the Partnership units and pays 5% of the 99% of these costs paid by the unit holders (4.95%).

 

RELP processes joint interest billings and revenue payments on behalf of the Partnership. At December 31, 2010 and 2009, RELP owed the Partnership $631,006 and $731,390, respectively, for net revenues processed in excess of joint interest and technical and administrative charges. The Partnership settles its balances with Reef and RELP on at least a quarterly basis.

 

If an affiliate of Reef serves as operator of a Partnership prospect, then operator fees are payable to the affiliate. Under such circumstances, such affiliate receives fees at the competitive rate in the geographical area where the prospect is located during the drilling and production phase of operations. These fees are charged as a monthly fee per well as agreed to in an operating agreement signed by the Partnership as well as outside third party working interest owners in the well. During the years ended December 31, 2010, 2009 and 2008, the Partnership paid operating overhead fees totaling $18,350, $17,235, and $14,105 to RELP.

 

The Partnership reimbursed to Reef legal fees of approximately $120,000 during the year ended December 31, 2010 related to the settlement of a lawsuit brought against Reef by a partner in the Partnership.  Reef prevailed in the defense of this lawsuit and a judgment was entered that dismissed the plaintiff’s claims.  Although the Partnership was not formally named a defendant in the litigation, the partner who brought the lawsuit was a partner in several Reef affiliates, including this Partnership, and his claim involved his participation in these Partnerships.  Pursuant to the Partnership Agreement, Reef is indemnified against litigation such as this, and the associated legal fees are to be reimbursed by the Partnership.  As of December 31, 2010, the Partnership owed Reef $237,847 for its share of additional legal fees associated with this activity.

 

**4. Major Customers**

 

The Partnership sells crude oil and natural gas on credit terms to refiners, pipelines, marketers, and other users of petroleum commodities. Revenues are received directly from these parties or, in certain circumstances, paid to the operator of the property who disburses to the Partnership its percentage share of the revenues. During the year ended December 31, 2010, one marketer and one operator accounted for 57.6% and 33.6% of the Partnership’s crude oil and natural gas revenues, respectively. During the year ended December 31, 2009, one marketer and one operator

 

F-10

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Table of Contents

 

Reef Global Energy VI, L.P.

Notes to Financial Statements (continued)

 

accounted for 51.3% and 31.2% of the Partnership’s crude oil and natural gas revenues, respectively.  During the year ended December 31, 2008, one marketer and two operators accounted for 57.2%, 17.4%, and 11.4% of the Partnership’s crude oil and natural gas revenues, respectively. Due to the competitive nature of the market for purchase of crude oil and natural gas, the Partnership does not believe that the loss of any particular purchaser would have a material adverse impact on the Partnership.

 

**5. Commitments and Contingencies**

 

On August 26, 2010, Frank Stevenson (“Stevenson”) filed a lawsuit, styled *Stevenson v. Wayne Kirk, Michael J. Mauceli, Reef Global Energy Ventures II*, et al., Cause No. 10-10647, in the 191st Judicial District Court, Dallas County, Texas. The suit also names as defendants Reef Global Energy VI, L.P. and multiple other Reef-sponsored ventures and limited partnerships, as well as Reef Securities, Inc., among others.  On September 22, 2010, James and Carol Estle (the “Estles”) and Nancy Dykes Thurmond Antolic (“Antolic”) joined the suit as additional plaintiffs. On January 27, 2011, Donna Stevenson (Frank Stevenson’s spouse) and Jaimie Davis (“Davis”) joined the suit as additional plaintiffs. With respect to Davis’s claims, specifically, Reef Securities, Inc. did not offer or sell the interests in the Reef program that Davis purchased. Rather, she purchased her interests through an unaffiliated broker/dealer. In the First Amended Petition, plaintiffs alleged that, collectively, they were seeking in excess of $1 million in compensatory damages as well as exemplary damages, attorneys’ fees, pre- and post-judgment interest, and costs.  In the Second Amended Petition, plaintiffs seek an undisclosed, unspecified amount of damages. Plaintiffs assert claims of fraud, rescission under the Texas Securities Act, control person liability under the Texas Securities Act, and breach of fiduciary duty. Plaintiff Davis asserts against defendant Reef Oil & Gas Income and Development Fund, L.P. a claim for tortious interference with an existing contract.  Defendants believe plaintiffs’ claims are meritless, and with respect to many of the Reef programs named in the petition, defendants believe that the claims for fraud are barred by limitations, as are any claims for rescission or breach of fiduciary duty with respect to those programs. In addition, with respect to all Reef programs in which plaintiffs participated, each plaintiff received offering documents that thoroughly disclosed all material facts and risks associated with participation in such programs, particularly the fact that no guarantees or promises could be made or relied upon. Defendants (including Reef Global Energy VI, L.P.) intend to vigorously defend the lawsuit and may seek damages from plaintiffs based upon, among other things, breaches of representations and warranties made by them as well as the indemnification provisions of the documents executed by each of them. As of this time, no substantive discovery has been conducted, and no trial date has been set. As of December 31, 2010, the Partnership has accrued no amounts related to this litigation.

 

**6.  Partnership Equity**

 

Sales of Partnership units began on July 8, 2005. Proceeds received were placed into an interest bearing escrow account until the Partnership reached the minimum subscription level of 40 units. The Partnership was formed on July 18, 2005, and the sale of Partnership units was closed on October 31, 2005. The Partnership raised $35,797,434 from the sale of 1,431.897 Partnership units to investor partners. Reef purchased 75.363 units (5%) for $1,601,464. Reef also contributes 1% of all leasehold, drilling, and completion costs when incurred, in addition to having paid its pro rata share (4.95%) of the leasehold, drilling, and completion costs paid by the Partnership. In connection with this obligation, Reef has contributed $316,361 to the Partnership at December 31, 2010.

 

All units, except those purchased by Reef, paid a 15% management fee to Reef to pay for Partnership organization and offering costs, including sales commissions. These costs totaled $5,369,615, leaving net capital contributions of $32,345,644 available for Partnership oil & gas activities. Of the $5,369,615 management fee, offering costs were $5,319,615 and organization costs were $50,000. The Partnership has participated in the drilling of fifty-one wells at December 31, 2010, and has completed drilling operations with the capital raised by the Partnership.

 

Reef exclusively manages and controls all aspects of the business of the Partnership. The Partnership agreement prohibits participation by investor partners in the Partnership’s day-to-day business decisions.

 

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Table of Contents

 

Reef Global Energy VI, L.P.

Notes to Financial Statements (continued)

 

**7. Supplemental Information on Oil & Natural Gas Exploration and Production Activities**

** (unaudited)**

 

**Capitalized Costs**

 

The following table presents the Partnership’s aggregate capitalized costs relating to oil and gas activities at the end of each of the years indicated:

 
| **December 31,**                                  | ** ** | **2010**       | ** **    | **2009**       | ** ** | **2008**       | ** ** |
|--------------------------------------------------------|------------|----------------|---------------|----------------|------------|----------------|------------|
| ** **                                             | ** ** | ** **     | ** **    | ** **     | ** ** | ** **     | ** ** |
| **Oil and gas properties:**                            | ** ** | ** **     | ** **    | ** **     | ** ** | ** **     | ** ** |
| Proved properties                                      | ** ** | **$**          | 33,596,816    | ** **     | **$**      | 33,539,249     | ** ** | **$** | 33,228,110 | ** ** |
| ** **                                             | ** ** | **33,596,816** | ** **    | **33,539,249** | ** ** | **33,228,110** | ** ** |
| Less:                                                  |       |           |          |           |       |           |       |
| Accumulated depreciation, depletion and   amortization |       | (9,356,540     | )             | (7,696,715     | )          | (5,349,270     | )          |
| Property impairment                                    |       | (22,241,674    | )             | (22,241,674    | )          | (17,611,986    | )          |
| **Total**                                              | ** ** | **$**          | **1,998,602** | ** **     | **$**      | **3,600,860**  | ** ** | **$** | **10,266,854** | ** ** |

 

**Costs Incurred**

 

The following table sets forth costs incurred in oil and gas exploration and development activities during the years ended December 31, 2010, 2009, and 2008:

 
| ** **                  | ** ** | **2010**   | ** ** | **2009**   | ** ** | **2008**    | ** ** |
|-----------------------------|------------|------------|------------|------------|------------|-------------|------------|
| ** **                  | ** ** | ** ** | ** ** | ** ** | ** ** | ** **  | ** ** |
| **Oil and gas properties:** | ** ** | ** ** | ** ** | ** ** | ** ** | ** **  | ** ** |
| Exploration                 | ** ** | **$**      | 1,394      | ** ** | **$**      | 308,523     | ** ** | **$** | 1,362,999 | ** ** |
| Development                 |       | 56,177     |       | 2,612      |       | (127,071    | )          |
| **Total**                   | ** ** | **$**      | **57,571** | ** ** | **$**      | **311,135** | ** ** | **$** | **1,235,928** | ** ** |

 

**Results of Operations**

 

The following table sets forth results of operations from oil and gas producing activities for the years ended December 31, 2010, 2009, and 2008:

 
| ** **                               | ** ** | **2010**   | ** **    | **2009**   | ** ** | **2008**       | ** ** |
|------------------------------------------|------------|------------|---------------|------------|------------|----------------|------------|
| ** **                               | ** ** | ** ** | ** **    | ** ** | ** ** | ** **     | ** ** |
| **Oil and gas producing   activities:**  | ** ** | ** ** | ** **    | ** ** |       |           |       |
| Crude oil sales                          | ** ** | **$**      | 2,410,743     | ** ** | **$**      | 1,977,788      | ** ** | **$** | 3,273,008 | ** ** |
| Natural gas sales                        |       | 2,016,472  |          | 2,741,607  |       | 6,171,151      |       |
| Production expenses                      |       | (542,507   | )             | (967,985   | )          | (1,444,240     | )          |
| Accretion of asset retirement obligation |       | (68,979    | )             | (22,310    | )          | (60,786        | )          |
| Depreciation, depletion and amortization |       | (1,725,156 | )             | (2,343,937 | )          | (2,320,505     | )          |
| Property impairment expense              |       | —     |          | (4,629,688 | )          | —         |       |
| **Results of producing activities**      | ** ** | **$**      | **2,090,573** | ** ** | **$**      | **(3,244,525** | **)**      | **$** | **5,618,628** | ** ** |
| ** **                               | ** ** | ** ** | ** **    | ** ** | ** ** | ** **     | ** ** |
| Depletion rate per BOE                   | ** ** | **$**      | 17.05         | ** ** | **$**      | 15.45          | ** ** | **$** | 16.23 | ** ** |

 

BOE = Barrels of Oil Equivalent (6 MCF equals 1 BOE)

 

**Crude Oil and Natural Gas Reserves**

 

**Net Proved Developed Reserve Summary**

 

The reserve information presented below is based upon estimates of net proved reserves that were prepared by the

 

F-12

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Table of Contents

 

Reef Global Energy VI, L.P.

Notes to Financial Statements (continued)

 

independent petroleum engineering firms Forrest A. Garb & Associates, Inc., as of December 31, 2010 and 2009, and by Gleason Engineering as of December 31, 2008.   Proved crude oil and natural gas reserves are the estimated quantities of crude oil and natural gas which geological and engineering data demonstrate with reasonable certainty to be economically recoverable in future years from known reservoirs under existing economic conditions, operating methods and governmental regulations (i.e. prices and costs as of the date the estimate is made).  Proved developed reserves are reserves that can be expected to be recovered through existing wells with existing equipment and operating methods.  At December 31, 2010, all of the Partnership’s reserves are classified as proved developed reserves.  All of the Partnership’s reserves are located in the United States.

 

The following sets forth changes in estimated net proved developed crude oil and natural gas reserves for the years ended December 31, 2010, 2009, and 2008.

 
| ** **                                                     | ** ** | **Oil********(BBL) (1)** | ** ** | **Gas********(mcf)** | ** ** | **BOE (2)** | ** ** |
|----------------------------------------------------------------|------------|-------------------------------|------------|----------------------|------------|------------------|------------|
| Net proved reserves for properties owned by the   Partnership: |       |                          |       |                 |       |             |       |
| Reserves at December 31, 2007                             |       | 186,993                       |       | 3,401,162            |       | 753,853          |       |
| Revisions of previous estimates                                |       | (53,994                       | )          | (538,377             | )          | (143,723         | )          |
| New discoveries                                                |       | 67                            |       | 28,543               |       | 4,824            |       |
| Production                                                     |       | (33,086                       | )          | (659,300             | )          | (142,969         | )          |
| Reserves at December 31, 2008                             | ** ** | **99,980**                    | ** ** | **2,232,028**        | ** ** | **471,985**      | ** ** |
|                                                           |       |                          |       |                 |       |             |       |
| Revisions of previous estimates                                |       | (6,911                        | )          | (798,079             | )          | (139,924         | )          |
| Production                                                     |       | (37,439                       | )          | (685,359             | )          | (151,666         | )          |
| Reserves at December 31, 2009                             | ** ** | **55,630**                    | ** ** | **748,590**          | ** ** | **180,395**      | ** ** |
| ** **                                                     | ** ** | ** **                    | ** ** | ** **           | ** ** | ** **       | ** ** |
| Reserves sold                                                  |       | —                        |       | (62,099              | )          | (10,350          | )          |
| Revisions of previous estimates                                |       | 27,814                        |       | 505,438              |       | 112,053          |       |
| Production                                                     |       | (34,584                       | )          | (399,549             | )          | (101,175         | )          |
| Reserves at December 31, 2010                             | ** ** | **48,860**                    | ** ** | **792,380**          | ** ** | **180,923**      | ** ** |

 

----

(1)                Oil includes both crude oil and gas liquids

(2)                BOE (barrels of oil equivalent) is calculated by converting 6 MCF of natural gas to 1 BBL of crude oil. A BBL (barrel) of crude oil is one stock tank barrel, or 42 U.S. gallons liquid volume, of crude oil or other liquid hydrocarbons.

 

**Standardized Measure of Discounted Future Net Cash Flows**

 

Certain information concerning the assumptions used in computing the valuation of proved reserves and their inherent limitations are discussed below.  The Partnership believes such information is essential for a proper understanding and assessment of the data presented.

 

For the years ended December 31, 2010 and 2009, future cash inflows are computed by applying the new SEC pricing, which holds constant the unweighted arithmetic average of the first-day-of-the-month prices for crude oil and natural gas over the preceding 12-month period as the price basis for estimating the Partnership’s proved reserves. For the years ended December 31, 2010 and 2009, calculations were made using average prices of $79.79 and $61.08 per barrel of crude oil, respectively, and $4.39 and $3.83 per MCF of natural gas, respectively. For the year ending December 31, 2008, future cash inflows were computed by applying the former SEC pricing rules, which hold constant the end-of-year price for crude oil and natural gas as the price basis for estimating the Partnership’s proved reserves. During 2008, the calculations were made using average prices of $44.60 per barrel of oil and $5.71 per MCF of natural gas.  Prices and costs are held constant for the life of the wells, however, prices are adjusted by well in accordance with sales contracts, energy content quality, transportation, compression and gathering fees, and regional price differentials.

 

F-13

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Table of Contents

 

Reef Global Energy VI, L.P.

Notes to Financial Statements (continued)

 

These assumptions used to compute estimated future cash inflows do not necessarily reflect Reef’s expectations of the Partnership’s actual revenues or costs, nor their present worth. Further, actual future net cash flows will be affected by factors such as the amount and timing of actual production, supply and demand for crude oil and natural gas, and changes in governmental regulations and tax rates. Sales prices of both crude oil and natural gas have fluctuated significantly in recent years. Reef, as managing general partner, does not rely upon the following information in making investment and operating decisions for the Partnership.

 

Future development and production costs are computed by estimating the expenditures to be incurred in developing and producing the proved crude oil and natural gas reserves at the end of the year, based on year-end costs and assuming continuation of existing economic conditions.

 

A 10% annual discount rate is used to reflect the timing of the future net cash flows relating to proved reserves.

 
| **December 31,**                            | ** ** | **2010**      | ** **    | **2009**      | ** ** | **2008**       | ** ** |
|--------------------------------------------------|------------|---------------|---------------|---------------|------------|----------------|------------|
| Oil and gas properties owned by the Partnership: |       |          |          |          |       |           |       |
| Future cash inflows                              | ** ** | **$**         | 7,919,740     | ** **    | **$**      | 6,293,210      | ** ** | **$** | 17,876,444 | ** ** |
| Future production costs                          |       | (2,274,580    | )             | (2,111,280    | )          | (4,552,354     | )          |
| Future development costs                         |       | —        |          | (79,290       | )          | —         |       |
| Future net cash flows                            | ** ** | **5,645,160** | ** **    | **4,102,640** | ** ** | **13,324,090** | ** ** |
| Effect of discounting net cash flows at 10%      |       | (755,050      | )             | (501,780      | )          | (2,672,141     | )          |
| Discounted future net cash flows                 | ** ** | **$**         | **4,890,110** | ** **    | **$**      | **3,600,860**  | ** ** | **$** | **10,651,949** | ** ** |

 

Changes in the Standardized Measure of Discounted Future Net Cash flows Relating to Proved Crude Oil and Natural Gas Reserves

 
| **December 31,**                              | ** ** | **2010**   | ** **    | **2009**   | ** ** | **2008**      | ** ** |
|----------------------------------------------------|------------|------------|---------------|------------|------------|---------------|------------|
| Oil and gas properties owned by the Partnership:   |       |       |          |       | ** ** | ** **    | ** ** |
| Standardized measure at beginning of period        |       | $          | 3,600,860     |       | $          | 10,651,949    |       | $ | 23,341,108 |   |
| Extensions and discoveries                         |       | —     |          | —     |       | 107,475       |       |
| Net change in sales price, net of production costs |       | 1,553,809  |          | (1,825,180 | )          | (4,653,321    | )          |
| Revisions of quantity estimates                    |       | 2,979,546  |          | (2,847,002 | )          | (3,245,873    | )          |
| Net changes in estimated future development costs  |       | —     |          | (69,592    | )          | 29,491        |       |
| Changes in production timing rates                 |       | 346,489    |          | 354,590    |       | 678,091       |       |
| Accretion of discount                              |       | 360,086    |          | 1,065,195  |       | 2,334,111     |       |
| Sales net of production costs                      |       | (3,815,729 | )             | (3,729,100 | )          | (7,939,133    | )          |
| Sales of minerals in place                         |       | (134,951   | )             | —     |       | —        |       |
| Net increase (decrease)                            |       | 1,289,250  |          | (7,051,089 | )          | (12,689,159   | )          |
| Standardized measure at end of year                | ** ** | **$**      | **4,890,110** |       | $          | **3,600,860** |       | $ | **10,651,949** |   |

 

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