UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-K

(Mark One)

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

For The Fiscal Year Ended December 31, 2013

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 x 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 27, 2014, the registrant had 75.363 units of general partner interest 2.893 units of limited partner interest held by the managing general partner, and 1,429.004 units of limited partner interest outstanding.

Documents incorporated by reference: None

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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 upon which it participated in the drilling of twenty-seven developmental wells. The Partnership purchased working interests in fourteen exploratory prospects upon which it participated in the drilling of sixteen exploratory wells 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 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, serves as operator of the prospect. RELP originally served as operator of eight developmental and four exploratory Partnership prospects.

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 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 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.

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Drilling and Completion Phase of Operations

On all prospects 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. The Partnership retains ownership of successful wells until they are either sold or they cease operations and are plugged and abandoned. The Partnership participated in the drilling of twenty-three successful and twelve unsuccessful developmental wells, and eight successful and eight unsuccessful exploratory wells on the thirty-four Partnership prospects. Of these thirty-one successful wells, eight are productive, eight have been plugged and abandoned, ten have been sold, one well that was shut-in was transferred to a third party working interest owner in the well during the fourth quarter of 2013 in exchange for his assumption of the Partnership’s plugging obligation, three wells are shut-in awaiting plugging and abandonment, and one well was shut-in during June 2013 and, following two unsuccessful workover procedures performed during August and November 2013, remains shut-in as of December 31, 2013. After careful evaluation, the Partnership intends not to participate in any future proposals relating to this well.

Operations on seven of the developmental and three of the exploratory prospects operated by RELP have ceased as a result of the sale or plugging and abandonment of the wells drilled on those prospects. RELP is the operator of one productive developmental well and one shut-in exploratory well as of December 31, 2013. The shut-in exploratory well was plugged and abandoned during the first quarter of 2014. 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. The Partnership also has a working interest in six successful developmental and one successful exploratory well located on one exploratory prospect operated by a third party.

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 the drilling of twenty-three successful developmental wells and eight successful exploratory wells. Of these wells, seven developmental and one exploratory well are productive as of December 31, 2013. RELP is the operator of one of the productive developmental wells, and the remaining productive wells are operated by a third party.

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.

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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.”

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, 2013, two operators and one marketer accounted for 42.2%, 28.3%, and 29.3% of the Partnership’s crude oil and natural gas revenues, respectively. During the year ended December 31, 2012, two operators and one marketer accounted for 63.3%, 12.0%, and 23.4% of the Partnership’s crude oil and natural gas revenues, respectively. During the year ended December 31, 2011, one operator and one marketer accounted for 75.0% and 15.9% 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 a joint and several liability 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 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.

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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.

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 and solar 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 also 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.

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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.

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.”

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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;

· 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.

The Partnership does not intend, and is not expected, to continue as a going concern.

The original business plan for the Partnership was to use its initial capital to purchase working interests in oil and gas prospects, participate in the drilling of oil and gas wells on those prospects, retain ownership of successful wells until they were either sold or ceased operations, and distribute net operating cash flows to the investor partners. It was not expected that net operating cash flows would be reinvested in the business other than such funds as would be necessary to maintain operation of the original wells drilled by the Partnership.

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The Partnership has had two significant producing properties. These two properties accounted for approximately 73.7% of total Partnership revenues during 2012, and 83.6% of total Partnership revenues during the six month period ended June 30, 2013. During the latter part of June one of these two wells ceased production, and two workover procedures performed on the well failed to restore production. As a result the well continues to be shut-in at December 31, 2013 and, after careful consideration, the Partnership has decided it will not participate in any future operations on this property. The Partnership is responsible for plugging and abandonment costs, unless the Partnership interest is assumed by third parties interested in attempting to return the well to productive status through additional drilling and workover procedures. The second significant property has an estimated remaining economic reserve life of 7 months, utilizing current prices, costs, and projected production volumes at December 31, 2013. This property accounted for 67.3% of total Partnership revenues during the last six months of 2013. The Partnership has no plans to drill additional wells. The Partnership also has no plans to engage in commodity futures trading or hedging activities. Finally, the estimated economic reserve life of Partnership wells is computed based upon operating revenues and costs and does not consider Partnership general and administrative costs. Future cash flows generated from Partnership wells will be significantly impacted by actual prices received subsequent to December 31, 2013, and by actual production volumes. Current projections indicate that subsequent to December 31, 2013, revenues generated from crude oil and natural gas sales will not be sufficient to cover operating expenses and general and administrative costs. Reef, as the Partnership’s managing general partner and sole general partner, will be required to provide additional capital contributions to the Partnership should working capital and future cash generated from crude oil and natural gas sales not be sufficient to settle all remaining asset retirement obligations and pay operating and general and administrative costs. During 2013, Reef made a capital contribution totaling $100,000 to the Partnership. Our independent registered public accounting firm’s opinion on our 2013 financial statements includes an explanatory paragraph indicating substantial doubt about our ability to continue as a going concern.

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, 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 26.3% of the Partnership’s estimated proved reserves were crude oil reserves and 73.7% were natural gas reserves at December 31, 2013. 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.

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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.

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.

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, 2013 are based upon the preceding 12-month un-weighted arithmetic average of the first-day-of-the-month prices and costs in effect at December 31, 2013. 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.

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

The Partnership has a significant producing property located in the coastal region of Texas in Galveston County. 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 service contractors. Many of our competitors are larger, well-established 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 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 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 only has nominal funds available for Partnership purposes unless there are revenues from Partnership operations. Any future requirement for additional funding for development, operations, and asset retirement will have to come from the Partnership’s working capital or future net revenues. Reef cannot assure the partners that Partnership operations will be sufficient to provide the Partnership with necessary additional funding. Reef, as the Partnership’s managing general partner and sole general partner, will be required to provide additional capital contributions to the Partnership should working capital and future cash generated from crude oil and natural gas sales not be sufficient to settle all remaining asset retirement obligations and pay operating and general and administrative costs. During 2013, Reef made a capital contribution totaling $100,000 to the Partnership.

The Partnership may incur liabilities 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.

ITEM 1B. UNRESOLVED STAFF COMMENTS

None.

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ITEM 2. PROPERTIES

Drilling Activities and Productive Wells

The Partnership purchased working interests in prospects 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 sixteen successful developmental wells on nine developmental prospects located in Acadia Parish, Louisiana, Pittsburg County, Oklahoma, Eddy County, New Mexico and Palo Pinto, Jackson, Harris, Galveston, and Lavaca (2 prospects) County, Texas. The Partnership participated in drilling 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. Five of the successful developmental wells were previously plugged and abandoned between 2007 and 2009, two of the successful wells were sold during 2010, and eight of the successful wells were sold during the first quarter of 2013. As of December 31, 2013, one successful developmental well was productive.

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 participated in drilling 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. Three of the successful exploratory wells were previously plugged and abandoned between 2006 and 2010. As of December 31, 2013, six successful development wells and one successful exploratory well were productive. Of the remaining successful exploratory wells, one was transferred to a third party working interest owner in the well during the fourth quarter of 2013 in exchange for his assumption of the Partnership’s plugging obligation, and three were shut-in awaiting plugging and abandonment. One developmental well, the Rob L. RA SUA CL&F #1 (“Gumbo II”) well was shut-in during the latter part of June 2013, and, following two unsuccessful workover procedures performed during August and November 2013, remains shut-in as of December 31, 2013. After careful evaluation, the Partnership intends not to participate in any future proposals relating to the Gumbo II well

On March 12, 2013, the Partnership, along with Reef Oil & Gas income and Development Fund II, L.P., Reef Global Energy VII, L.P., Reef Global Energy VIII, L.P., and Reef Global Energy IX, L.P. (collectively, the “Sellers”), sold, transferred, assigned, and conveyed all of their rights, title and interest in the Sand Dunes property in Eddy County, New Mexico effective as of March 1, 2013 to Penroc Oil Corporation for an aggregate purchase price to the Sellers of $100,000. The Partnership received approximately $8,600 of the purchase price, net of fees associated with the sale. The Sand Dunes property included eight wells, of which one had been converted into a salt water disposal well during 2010. The Sand Dunes property accounted for approximately 1.0% of the Partnership’s total sales revenues during the year ended December 31, 2012. Prior to the sale, RELP had served as the operator of the eight successful developmental wells located on the Sand Dunes property.

During the fourth quarter of 2013, RELP, as operator, proposed the plugging and abandonment of a shut-in well in which the Partnership held a working interest. In accordance with the operating agreement, one of the other working interest owners elected to take over operations of the well. The Partnership assigned its working interest to the third party, and RELP resigned as operator and turned operations over to the third party. In connection with this transaction, the third party assumed the Partnership’s asset retirement obligation of $41,599. The Partnership recorded the disposition of the asset retirement obligation as a gain on sale due to its significance to the Partnership’s rate of depletion.

Proved Crude Oil and Natural Gas Reserves

Estimates of the Partnership’s proved reserves are prepared and presented in accordance with SEC rules and accounting standards which require SEC reporting entities to prepare their reserve estimates using pricing based upon the un-weighted arithmetic average of the first-day-of-the-month commodity prices over the preceding 12-month period and current costs. All of the Partnership’s reserves are located in the United States.

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The estimated net proved crude oil and natural gas reserves at December 31, 2013, 2012, and 2011 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, 2011	35,140	878,880
Net proved reserves, December 31, 2012	3,980	186,890
Net proved reserves, December 31, 2013	1,820	30,530

The standardized measure of discounted future net cash flows as of December 31, 2013, 2012, and 2011 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 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, 2011	$	4,143,730
Standardized measure of discounted future net cash flows as of December 31, 2012	$	560,610
Standardized measure of discounted future net cash flows as of December 31, 2013	$	145,990

During the years ended December 31, 2013, 2012, and 2011, the Partnership recognized property impairment expense of proved properties totaling $257,785, $241,766, and $0, respectively, 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 engineering firm, Forrest A. Garb & Associates, Inc., (“FGA”) of Dallas, Texas, to prepare its December 31, 2013, 2012, and 2011 estimates of net proved crude oil and natural gas reserves. FGA estimated reserves for all of our properties as of December 31, 2013, 2012, and 2011. 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 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.

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. Jerald Sluder, Senior Reservoir Engineer for RELP, is primarily responsible for overseeing the preparation of reserve estimates by FGA. Mr. Sluder has a B.S. in Petroleum Engineering, is a Registered Professional Engineer in the State of Texas and has over nineteen years of industry experience in oil and gas operations. Mr. Sluder is an active member of the Society of Petroleum Engineers and of the Petroleum Engineers Club of Dallas. Any significant reserve changes are approved by Mr. Daniel C. Sibley, Chief Financial Officer and General Counsel of RELP, and Mr. Michael J. Mauceli, Chief Executive Officer of RELP.

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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 Securities, Inc., Paul Mauceli, and multiple other Reef-sponsored ventures and limited partnerships, among others (collectively, “Defendants”). On September 22, 2010, via Plaintiffs’ First Amended Original Petition, 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 Jaime Davis (“Davis”) joined the suit as additional plaintiffs (Stevenson, Estles, Antolic, and Davis are collectively referred to as “Plaintiffs”) via Plaintiffs’ Second Amended Original Petition. On September 19, 2012, Robert C. Phalen (“Phalen”) filed an Original Petition in Intervention in the case, alleging the same claims as the other Plaintiffs. With respect to Davis’s and Phalen’s claims, specifically, Reef Securities, Inc. did not offer or sell the interests in the Reef programs that either of them purchased. Rather, they each purchased their interests through an unaffiliated broker/dealer. On January 24, 2012, Plaintiffs filed their Sixth Amended Petition, by which Plaintiffs allege that, collectively, they are seeking in excess of $2.5 million in compensatory damages as well as exemplary damages, attorneys’ fees, pre- and post-judgment interest, and costs. Plaintiffs assert claims of misrepresentations and omissions under the Texas Securities Act (“TSA”), fraud, control person liability under the Texas Securities Act, breach of fiduciary duty, breach of contract, civil theft, negligent misrepresentation, and fraudulent concealment. Plaintiffs have represented they are dismissing their theft claims. 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 because, among other things, in connection with each Reef program 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. Plaintiffs also claim that Defendants misallocated costs, expenses and deductions among unidentified Reef-sponsored ventures and limited partnerships. Plaintiffs seek approximately $2.5 million as actual damages, $620,000 as exemplary damages, as well as attorneys’ fees, pre- and post-judgment interest, and costs. Defendants intend to vigorously defend the lawsuit and may seek damages from plaintiffs. Defendants filed Motions for Partial Summary Judgment seeking the dismissal of certain of Plaintiffs Stevenson, Estles, and Antolic’s claims. Following Defendants’ filing of their Motions for Summary Judgment, by filing their Sixth Amended Petition, Plaintiffs dismissed their claims for rescission under the TSA for failure of Defendants to register under the TSA, control person liability under the TSA in connection with such registration claims, and a majority of Plaintiffs’ fraud claims under the TSA. On December 18, 2012, the Court heard Defendants’ Joint Motion to Sever and Stay Claims of Plaintiff Jaimie Davis and to Sever Claims of Plaintiff Robert Phalen, and on that same date, the Court granted the Motion. Accordingly, Jaimie Davis’s claims have been severed and stayed, and are now pending under Cause of Action No. DC-13-00527 in the Dallas County District Court. Additionally, Robert Phalen’s claims have been severed and are now pending under Cause of Action No. DC-13-00528. As to the remaining Plaintiffs in the Stevenson matter, trial has been set for July 14, 2014. The Defendants intend to vigorously defend against these claims.

No accrual has been recorded as of December 31, 2013 as a loss is not believed to be probable. A reasonable estimate of a possible range of loss cannot be made. The Partnership is reimbursing Reef its share of the costs of defending this lawsuit as incurred and disclosed in Note 3 of the Audited Financial Statements presented in this Annual Report. The Partnership has reimbursed $101,482, $73,435, and $25,931, respectively, during the years ended December 31, 2013, 2012 and 2011.

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On December 22, 2011, TEPCO, LLC, Kiawah Resources, LLC, Meritage Energy, LLC and Ralph S. O’Connor (the “Plaintiffs”) filed a lawsuit styled TEPCO, LLC, Kiawah Resources, LLC, Meritage Energy, LLC and Ralph S. O’Connor v. Reef Exploration, L.P., RCWI, L.P., El Paso E&P Company, L.P., and Anchor International of Texas LP, Cause No. 2011-76727, in the 127th Judicial District Court of Harris County, Texas. On July 11, 2012, Plaintiffs filed a First Amended Petition whereby they added Reef Global Energy V, L.P., Reef Global Energy VI, L.P., and Reef Global Energy VII, L.P. as additional defendants (Reef Exploration, L.P., RCWI, L.P., Reef Global Energy V, L.P., Reef Global Energy VI, L.P. and Reef Global Energy VII, L.P. are collectively referred to as the “Reef Defendants”). In their Petition, Plaintiffs assert claims for alleged breaches of contracts in regard to the drilling and operation of an oil and gas well located in Galveston County, Texas. Plaintiffs seek compensatory damages in an unspecified amount as well as attorneys’ fees, pre- and post-judgment interest, and costs. On March 26, 2013, the court granted in part a motion for summary judgment submitted by the Reef Defendants and denied in full a motion for partial summary judgment submitted by Plaintiffs. The Partnership owns an interest in the well in question, and if the Plaintiffs were successful, the Partnership would be required to contribute its pro rata share to satisfy any judgment the Plaintiffs might receive. The trial of the case concluded on March 11, 2014. It is expected that the judge will render his judgment in the near future, but due to other trial commitments, his judgment could be delayed for a few months.

No accrual has been recorded as of December 31, 2013 as a loss is not believed to be probable. A reasonable estimate of a possible range of loss cannot be made. The Partnership is expensing its share of the costs of defending this lawsuit as incurred, and has paid and accrued legal fees of $378,022, $227,311, and $0, respectively, during the years ended December 31, 2013, 2012 and 2011.

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

PART II

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

As of December 31, 2013, the Partnership had one managing general partner, and 1,161 non-Reef investor partners (“investor partners”). Reef holds a total of 75.363 general partner units and 2.893 limited partner units and the investor partners hold 1,429.004 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 available for distribution to the partners in accordance with the Partnership Agreement. The Partnership began making cash distributions to the partners of interest income and crude oil and natural gas sales revenues, less operating and general and administrative costs, in December 2005. Prior to September 30, 2013, cash distributions were 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. As a result of the repurchase of units during 2013 (described below), the managing general partner will receive 0.20% of the 84.55% distributed to investor partners. The last cash distribution to partners occurred in September 2012. Current projections indicate that no funds will be available for future cash distributions to investor partners unless the Partnership has available cash after settling all remaining obligations of the Partnership, including asset retirement, operating and general and administrative costs.

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.

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The Partnership has 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. As the managing general partner, Reef purchased 2.893 units of limited partner interest from investor partners under the Partnership’s unit repurchase program during 2013.

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,
	2013			2012			2011			2010			2009

Revenue	$	487,867		$	1,480,082		$	3,809,120		$	4,427,215		$	4,719,395
Interest income	—			12			250			607			3,086
Miscellaneous income	—			1,230			—			—			—
Costs and expenses	(1,381,413		)	(1,642,117		)	(1,890,520		)	(3,238,699		)	(8,628,475		)
Net income (loss)	(893,546		)	(160,793		)	1,918,850			1,189,123			(3,905,994		)

Allocation of net income (loss):
Managing general partner units	(534,908		)	31,927			362,183			342,841			54,109
Limited partner units	(358,638		)	(192,720		)	1,556,667			846,282			(3,960,103		)
Net income (loss) per managing general partner unit	(7,097.75		)	423.64			4,805.84			4,549.20			717.98
Net income (loss) per limited partner unit	(250.46		)	(134.59		)	1,807.14			591.02			(2,765.63		)

Total assets	233,853			844,426			1,912,917			2,815,422			4,520,645
Distributions to managing general partner	—			111,616			399,012			481,675			475,948
Distributions to investor partners	—			719,977			2,183,589			2,635,960			2,604,624
Distributions per limited partner unit	—			491.04			1,524.96			1,840.89			1,819.00
Distributions per managing general partner unit	—			1,704.83			5,294.53			6,391.40			6,315.41

Operating Data
Annual sales volume:
Gas (MCF)	40,113			130,048			236,655			399,549			685,360
Oil (BBL)	4,686			12,106			29,111			34,584			37,439

Average sales price:
Gas (per MCF)	$	3.52		$	3.54		$	5.03		$	5.05		$	4.00
Oil (per BBL)	$	74.02		$	84.19		$	89.97		$	69.71		$	52.83

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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

Use of Estimates

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 barrels of oil equivalent (“BOE”) at a rate of 6 Mcf to 1 Bbl.

In applying the full cost method, 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 the sum of the estimated future net revenues from proved reserves using prices that are the preceding 12-month un-weighted 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. 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 statements of operations. The Partnership does not recognize gain or loss 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, 2013, 2012, and 2011, the Partnership recognized property impairment expense of proved properties totaling $257,785, $241,766, and $0, respectively. During the year ended December 31, 2013, the Partnership recognized gain of $132,803 related to property sales and dispositions. Of the recognized gain, $127,066 was attributable to the resulting reduction of asset retirement obligation.

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 engineering firm, FGA, at December 31, 2013, 2012, and 2011, 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 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.

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.

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The following table summarizes the Partnership’s asset retirement obligation (inclusive of the current portion) for the years ended December 31, 2013 and 2012.

	2013			2012
Beginning asset retirement obligation	$	364,864		$	394,823
Accretion expense	18,632			63,766
Retirement related to sale and disposition of proved properties	(127,066		)	—
Retirement related to property abandonment and restoration	(938		)	(93,725		)
Ending asset retirement obligation	$	255,492		$	364,864

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, 2013, 2012 and 2011, the Partnership had no material gas imbalance positions.

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 were used to purchase working interests in 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 operating and general and administrative costs, are distributed 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 temporarily reduced distributions to investor partners and utilized the cash flow from existing wells to pay for the drilling of these two wells. The Partnership does not plan to drill any additional wells on any Partnership prospect, or to acquire additional prospects.

The Partnership does not operate in any other industry segment. During the drilling and completion phase of operations, 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 purchased working interests in 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 participated in drilling thirty-five developmental and sixteen exploratory wells on these prospects between 2005 and 2009. 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 participated in drilling twenty-three successful developmental wells and twelve unsuccessful development wells. The Partnership participated in drilling eight successful exploratory and eight unsuccessful exploratory wells.

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Of these thirty-one successful wells, as of December 31, 2013 eight are productive, eight have been plugged and abandoned, ten have been sold, one well that was shut-in was transferred to a third party working interest owner in the well during the fourth quarter of 2013 in exchange for his assumption of the Partnership’s plugging obligation, three wells are shut-in awaiting plugging and abandonment, and one well was shut-in during June 2013 and, following two unsuccessful workover procedures performed during August and November 2013, remains shut-in as of December 31, 2013. After careful evaluation, the Partnership intends not to participate in any future proposals relating to this well.

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. Reef 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 exploratory well in March 2009, subsequent to the completion of the Partnership’s drilling phase. Expenditures in excess of available capital contributions were deducted from Partnership distributions.

Please see Item 1A of this Annual Report for a list of risk factors that could impact the Partnership. The Partnership distributes to investors the net cash flow from interest income and crude oil and natural gas sales revenues from successful wells, less operating and general and administrative costs. The last cash distribution to partners occurred in September 2012. Current projections indicate that no funds will be available for future cash distributions to investor partners unless the Partnership has available cash after settling all remaining obligations of the Partnership, including asset retirement, operating and general and administrative costs.

The Partnership had negative working capital of $279,823 at December 31, 2013. Subsequent to expending the initial available Partnership capital contributions on prospect acquisitions and drilling and completion costs of Partnership wells, the Partnership’s working capital consists primarily of cash flows from productive properties, which have been utilized to pay cash distributions to investors. Current projections indicate that no funds will be available for future cash distributions to investor partners unless the Partnership has available cash after settling all remaining obligations of the Partnership, including asset retirement, operating and general and administrative costs.

Reef, as the Partnership’s managing general partner and sole general partner, will be required to provide additional capital contributions to the Partnership should working capital and future cash flows not be sufficient to settle Partnership obligations. During 2013, Reef made a $100,000 capital contribution to the Partnership, and during the first quarter of 2014, Reef made an additional capital contribution of $219,107 to the Partnership. Reef may be required to provide additional capital contributions.

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Results of Operations

Year Ended December 31, 2013 compared to Year Ended December 31, 2012

The Partnership incurred a net loss of $893,546 for the year ended December 31, 2013. The net loss for the year ended December 31, 2013 includes a gain of $132,803 on the sale and disposition of properties. Excluding this gain, the Partnership incurred a net loss of $1,026,349 for the year ended December 31, 2013 compared to a net loss of $160,793 for the year ended December 31, 2012. The decrease in oil and gas revenues, as well as increased legal fees, were the most significant causes of the increased net loss for the year ended December 31, 2013.

Partnership crude oil and natural gas production volumes declined on a BOE basis by 66.3%, and sales revenues fell by 67.0% during the year ended December 31, 2013. A first quarter 2013 workover attempt on the Robertson #1 well, which accounted for 17.7% of total BOE sold during 2012, was unsuccessful in returning the well to a productive status, and the well will be plugged and abandoned during the first quarter of 2014. The Partnership’s most significant well, the Gumbo II well, ceased producing and was shut-in during June 2013. The Gumbo II well accounted for 54.5% of total BOE sold during 2012, and despite producing for less than half of 2013, accounted for 37.5% of total BOE sold during 2013. The Partnership paid its share of the expenses for two workover procedures during the second half of 2013 which attempted, unsuccessfully, to re-establish production from the Gumbo II well. After careful evaluation, the Partnership decided not to participate in any future procedures the well operator might propose for 2014. As a result, the Partnership will not own a share in any future production that could result from a successful attempt to restore production during 2014. The permanent loss of production from these two wells was the biggest factor in the declining sales revenues during 2013. The Partnership currently has eight remaining productive wells. Sales revenues from these eight wells totaled $79,509 during the fourth quarter of 2013. These eight wells will continue to experience natural production declines during 2014.

The Partnership has not and is currently not engaged in commodity futures trading, hedging activities, or derivative financial instrument transactions for trading or other speculative purposes. The Partnership sells a 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. At current production volume levels, projections indicate that subsequent to December 31, 2013 revenues generated from crude oil and natural gas sales will not be sufficient to cover operating expenses and general and administrative costs. The Partnership’s eight productive wells have remaining economic reserve lives ranging from 7 months to nine years.

Lease operating costs decreased from $337,472 during the year ended December 31, 2012 to $313,069 during the year ended December 31, 2013. The 2013 operating expenses include approximately $64,000 expended in workover costs for the attempts to restore production from the Robertson #1 well and the Gumbo II well. Production taxes declined at a rate slightly higher than the decline in sales revenues due to the fact that Louisiana, where the Partnership’s Gumbo II well is located, has a higher oil production tax rate than Texas, where the Partnership’s eight remaining productive wells are located.

Depreciation, depletion, and amortization decreased from $367,822 for the year ended December 31, 2012 to $229,561 for the year ended December 31, 2013. Property impairment charges of $241,766 incurred during 2012, and additional impairment charges of $195,806 incurred during the first quarter of 2013, which were related to the reduction of reserves on the Partnership’s Gumbo II and Robertson #1 wells, reduced the Partnership’s depletable basis for 2013.

General and administrative costs increased from $530,790 incurred during the year ended December 31, 2012 to $668,752 incurred during the year ended December 31, 2013. Legal fees, including fees related to the Stevenson and TEPCO litigation described in Note 5 of the Audited Financial Statements contained in this Annual Report, increased from $311,824 for the year ended December 31, 2012 to $489,728 during the year ended December 31, 2013. The increase in legal fees was partially offset by a reduction in the administrative overhead charge to the Partnership. The allocation of RELP’s overhead to the Partnership is a significant portion of general and administrative expenses, and is based upon several factors, including the level of drilling activity, revenues, and capital and operating expenditures of each partnership managed by Reef compared to the total levels of all such partnerships. The administrative overhead charge to the Partnership decreased from $115,297 for the year ended December 31, 2012 to $47,826 for the year ended December 31, 2013, as decreased levels of activity for this Partnership caused decreases in the overall allocation factors used in the allocation of RELP’s overhead.

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Year Ended December 31, 2012 compared to Year Ended December 31, 2011

During the year ended December 31, 2012, the Partnership incurred a net loss of $160,793 compared to net income of $1,918,850 for the year ended December 31, 2011. The decrease in net income between these comparative periods is the result of declines in production volumes from the Partnership’s two most significant remaining wells and in oil and gas sales prices, property impairment cost, and increased legal fees related to the TEPCO Litigation.

Partnership crude oil and natural gas production volumes are declining due to natural production declines from existing wells combined with the fact that the Partnership has not drilled any new productive wells since 2008 and has no plans to conduct additional drilling activity. The Partnership share of production volumes from the two most significant wells in which the Partnership owns a working interest, the Gumbo II and the HBR A Big Gas well (“HBR A”), totaled 27,055 barrels of crude oil and 165,271 Mcf of natural gas, or 92.9% and 69.8% of Partnership production volumes, during the year ended December 31, 2011. During the year ended December 31, 2012, the Partnership share of production volumes from these two wells totaled 10,617 barrels of crude oil and 79,176 Mcf of natural gas, or 87.7% and 60.9% of Partnership production volumes, a volume drop of approximately 56.4% on an BOE basis. Beginning in August 2011, as water volumes associated with the production of the crude oil and natural gas from the Gumbo II well began to increase, the actual production volumes of crude oil and natural gas from the well began to decrease. The HBR A well has also experienced production declines as water volumes have increased. Production from existing Partnership wells will continue to decline in future quarters. The economic life of the Partnership is dependent upon the lives of the most significant wells in which it participates. The current remaining economic reserve lives of the Gumbo II well and the HBR A well are estimated to be approximately 11 and 23 months, respectively, using prices prepared in accordance with SEC rules and accounting standards and current costs.

The sales price for crude oil decreased by 6.4%, to an average price of $84.19 per Bbl for the year ended December 31, 2012, compared to an average price of $89.97 for the year ended December 31, 2011, and the sales price for natural gas decreased by 29.6% to an average price of $3.54 per Mcf for the year ended December 31, 2012, compared to an average price of $5.03 per Mcf for the year ended December 31, 2011.

The combination of declining production volumes and sales prices caused revenues to decrease by $2,329,038, or 61.1%, on a comparative period-to-period basis. The Partnership has not and is currently not engaged in commodity futures trading, hedging activities, or derivative financial instrument transactions for trading or other speculative purposes. The Partnership sells a 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. Current projections indicate that subsequent to December 31, 2012, revenues generated from crude oil and natural gas sales will not be sufficient to cover operating expenses and general and administrative costs.

Lease operating costs decreased from $418,583 during the year ended December 31, 2011 to $337,472 during the year ended December 31, 2012, primarily due to decreases in ad valorem taxes, marketing and gathering expenses, and workover expenses. Higher water disposal charges associated with the Gumbo II well have been offset by decreasing gas marketing and gathering expenses. Production taxes decreased from $306,301 during the year ended December 31, 2011 to $100,501 during the year ended December 31, 2012 due primarily to the decline in sales revenues.

The Partnership incurred $367,822 of depletion, depreciation, and amortization expense and $241,766 of property impairment expense during the year ended December 31, 2012, compared to $713,792 of depletion, depreciation, and amortization expense and no property impairment expense during the year ended December 31, 2011. Declining production rates between the comparative periods led to a reduced depletion rate applied to the Partnership’s depletable property basis. The impairment expense of $241,766 incurred during the year ended December 31, 2012 was the result of the reduction in the economic reserve life of the Gumbo II well, which reduced the Partnership’s economic recoverable reserves.

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General and administrative costs increased from $436,544 incurred during the year ended December 31, 2011 to $530,790 incurred during the year ended December 31, 2012. Legal fees reimbursed to RELP increased from $35,783 during the year ended December 31, 2011 to $311,824 during the year ended December 31, 2012, primarily due to expenses related to the TEPCO Litigation. The increase in legal fees was partially offset by a reduction in the administrative overhead charge to the Partnership. The administrative overhead charge to the Partnership decreased from $297,159 for the year ended December 31, 2011 to $115,297 for the year ended December 31, 2012. The allocation of RELP’s overhead to the Partnership is a significant portion of general and administrative expenses, and is based upon several factors, including the level of drilling activity, revenues, and capital and operating expenditures of each partnership managed by Reef compared to the total levels of all such partnerships.

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, 2013 and 2012, 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, 2013.

ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT MARKET RISK

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 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, 2013, a 10% change in the price received for our crude oil would have had an approximate $34,706 impact on our crude oil revenues, and a 10% change in the price received for our natural gas would have had an approximate $14,274 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.

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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 (1992). 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, 2013.

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.

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, 2013 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	57	Manager of Reef Oil & Gas Partners GP, LLC; Chief Executive Officer of RELP
Daniel C. Sibley	62	Chief Financial Officer and General Counsel of RELP
David M. Tierney	61	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.

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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 Laws-Taxation degree (Ll.M.) from Southern Methodist University in 1984. Mr. Sibley became a certified public accountant in 1977, but no longer maintains that license. He is an active member of the Texas Bar Association.

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.

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.

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

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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 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 initially purchased 5.00% of the outstanding Partnership units (75.363 units). During 2013, Reef purchased 2.893 units of limited partnership interest under the terms of the Partnership’s unit repurchase program. The 78.256 units owned by Reef are 5.19% of the total outstanding units, and represent 4.62% of the 89% interest in the Partnership held by the unit holders. Reef has a total interest in the Partnership of 15.62%.

Reef received a management fee equal to 15% of the Partnership subscriptions exclusive of the units initially purchased by Reef. From this amount Reef paid all of the Partnership’s organization and offering costs, including sales commissions. The management fee was 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 was 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 was $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, 2013, 2012, and 2011, the Partnership reimbursed Reef $61,811, $140,027, and $315,893, respectively, for administrative costs included as general and administrative expenses. The Partnership incurred no technical services costs capitalized as project costs during the years ended December 31, 2013, 2012, and 2011.

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, 2013, 2012, and 2011, the Partnership paid operating overhead fees totaling $12,733, $21,431, and $20,609 to RELP. As of December 31, 2013, RELP serves as operator for two Partnership prospects containing one productive well and one shut-in well plugged and abandoned during the first quarter of 2014.

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, 2013 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.

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)	78.256	5.19	%	4.62	%
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 initially purchased 5% of the 1,507.260 Partnership units (75.363) and, during 2013 purchased 2.893 units (0.19%) of limited partner interest under the terms of the Partnership’s unit repurchase program. Therefore, Reef currently holds 5.19% of the 89% interest in the Partnership (4.62%) held by the unit holders.

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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:

	2013		2012
Audit fees	$	39,001	$	49,741
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 (Deficit)	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 reference herein are indicated as such by the information supplied in the parenthetical thereafter. Otherwise, the exhibits are filed herewith.

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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.

101.INS*		XBRL Instance Document

101.SCH*		XBRL Taxonomy Extension Schema Document

101.CAL*		XBRL Taxonomy Extension Calculation Linkbase Document

101.LAB*		XBRL Taxonomy Extension Labels Linkbase Document

101.PRE*		XBRL Taxonomy Extension Presentation Linkbase Document

101.DEF*		XBRL Taxonomy Extension Definition Linkbase Document

* Filed herewith

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Report of Independent Registered Public Accounting Firm

The Partners

Reef Global Energy VI, L.P.

Richardson, Texas

We have audited the accompanying balance sheets of Reef Global Energy VI, L.P. as of December 31, 2013 and 2012, and the related statements of operations, partnership equity (deficit), and cash flows for each of the three years in the period ended December 31, 2013. 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. Our audits included 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, 2013 and 2012, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2013, in conformity with accounting principles generally accepted in the United States of America.

The accompanying financial statements have been prepared assuming that the Partnership will continue as a going concern. As discussed in Note 1 to the financial statements, the Partnership has one significant producing property that has a limited estimated economic reserve life as of December 31, 2013. Future cash flows generated from Partnership wells will be significantly impacted by actual prices received subsequent to December 31, 2013 and by actual production volumes from the Partnership’s most significant well. Current projections indicate that subsequent to December 31, 2013, revenues generated from crude oil and natural gas sales will not be sufficient to cover operating expenses and general and administrative costs. These and other factors raise substantial doubt about the Partnership’s ability to continue as a going concern. The financial statements do not include any adjustments that might result from the outcome of this uncertainty.

/s/ BDO USA, LLP

Dallas, Texas

March 27, 2014

F-1

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Reef Global Energy VI, L.P.

Balance Sheets

December 31,	2013			2012

Assets

Current assets:
Cash and cash equivalents	$	167,279		$	148,550
Accounts receivable	—			1,374
Accounts receivable from affiliates	—			133,892
Total current assets	167,279			283,816

Oil and gas properties, full cost method of accounting:
Proved properties, net of accumulated depletion of $33,449,711 and $33,040,929	66,574			560,610
Net oil and gas properties	66,574			560,610

Total assets	$	233,853		$	844,426

Liabilities and partnership equity

Current liabilities:
Accounts payable	$	113,228		$	39,990
Accounts payable to affiliates	219,107			—
Current portion of asset retirement obligation	114,767			157,286
Total current liabilities	447,102			197,276

Long-term liabilities:
Asset retirement obligation	140,725			207,578
Total long-term liabilities	140,725			207,578

Commitments and contingencies (Note 5)

Partnership equity (deficit)
Limited partners	—			358,638
Managing general partner	(353,974		)	80,934
Partnership equity (deficit)	(353,974		)	439,572

Total liabilities and partnership equity (deficit)	$	233,853		$	844,426

See accompanying notes to financial statements.

F-2

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Reef Global Energy VI, L.P.

Statements of Operations

	For the Years Ended December 31,
	2013			2012			2011

Revenues	$	487,867		$	1,480,082		$	3,809,120

Costs and expenses:
Lease operating expenses	313,069			337,472			418,583
Production taxes	26,417			100,501			306,301
Depreciation, depletion and amortization	229,561			367,822			713,792
Property impairment	257,785			241,766			—
Accretion of asset retirement obligation	18,632			63,766			15,300
General and administrative	668,752			530,790			436,544
Gain on sale of oil and gas properties	(132,803		)	—			—
Total costs and expenses	1,381,413			1,642,117			1,890,520

Income (loss) from operations	(893,546		)	(162,035		)	1,918,600

Other income:
Interest income	—			12			250
Miscellaneous income	—			1,230			—
Total other income	—			1,242			250

Net income (loss)	$	(893,546	)	$	(160,793	)	$	1,918,850

Net income (loss) per limited partner unit	$	(250.47	)	$	(134.59	)	$	1,807.14
Net income (loss) per managing general partner unit	$	(7,097.75	)	$	423.64		$	4,805.84

See accompanying notes to financial statements.

F-3

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Reef Global Energy VI, L.P.

Statements of Partnership Equity (Deficit)

	Limited partners				Managing general partner				Total
	Units	Amount			Units	Amount			Units	Amount
Balance at December 31, 2010	1,431.897	$	1,881,392		75.363	$	214,317		1,507.260	$	2,095,709
Partner distributions	—	(2,183,589		)	—	(399,012		)	—	(2,582,601		)
Net income	—	1,556,667			—	362,183			—	1,918,850
Balance at December 31, 2011	1,431.897	$	1,254,470		75.363	$	177,488		1,507.260	$	1,431,958

Distribution amount per partnership unit		$	1,524.96			$	5,294.53

Balance at December 31, 2011	1,431.897	1,254,470			75.363	177,488			1,507.260	1,431,958
Partner distributions (Note 2)	—	(703,112		)	—	(128,481		)	—	(831,593		)
Net income (loss)	—	(192,720		)	—	31,927			—	(160,793		)
Balance at December 31, 2012	1,431.897	$	358,638		75.363	$	80,934		1,507.260	$	439,572

Distribution amount per partnership unit		$	491.04			$	1,704.83

Balance at December 31, 2012	1,431.897	358,638			75.363	80,934			1,507.260	439,572
Partner contributions	—	—			—	100,000			—	100,000
Partner distributions	—	—			—	—			—	—
Net income (loss)	—	(358,638		)	—	(534,908		)	—	(893,546		)
Balance at December 31, 2013	1,431.897	$	—		75.363	$	(353,974	)	1,507.260	$	(353,974	)

Distribution amount per partnership unit		$	—			$	—

See accompanying notes to financial statements.

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Reef Global Energy VI, L.P.

Statements of Cash Flows

	For the Years Ended December 31,
	2013			2012			2011
Operating Activities
Net income (loss)	$	(893,546	)	$	(160,793	)	$	1,918,850
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
*Adjustments for non-cash transactions:*
Depreciation, depletion and amortization	229,561			367,822			713,792
Property impairment	257,785			241,766			—
Accretion of asset retirement obligation	18,632			63,766			15,300
Gain on sale of oil and gas properties	(132,803		)
Plugging and abandonment costs paid from ARO	(938		)	—			(2,515		)
*Changes in operating assets and liabilities:*
Accounts receivable	1,374			(1,374		)	2,895
Accounts receivable from affiliates	133,892			311,111			186,003
Accounts payable	73,238			(21,146		)	42,764
Accounts payable to affiliates	219,107			(25,000		)	(246,514		)
Net cash provided by (used in) operating activities	(93,698		)	776,152			2,630,575

Investing Activities
Proceeds from sale of property	8,430			—			—
Property acquisition and development	3,997			(11,632		)	(15,270		)
Net cash provided by (used in) investing activities	12,427			(11,632		)	(15,270		)

Financing Activities
Partner contributions	100,000			—			—
Partner distributions	—			(831,593		)	(2,582,601		)
Net cash provided by (used in) financing activities	100,000			(831,593		)	(2,582,601		)

Net increase (decrease) in cash and cash equivalents	18,729			(67,073		)	32,704
Cash and cash equivalents at beginning of period	148,550			215,623			182,919
Cash and cash equivalents at end of period	$	167,279		$	148,550		$	215,623

Non-cash investing transactions
Asset retirement obligation reduction resulting from sale and disposition of proved properties	$	127,066		$	—		$	—
Adjustment to asset retirement obligation	$	—		$	93,725		$	25,610

See accompanying notes to financial statements.

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Reef Global Energy VI, L.P.

Notes to Financial Statements

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 at inception 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.

Upon completion of the Partnership’s drilling program in 2008, all general partner units held by investors other than the managing general partner were converted into limited partner units.

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. Reef purchased 2.893 units (0.19%) of limited partner interest from investor partners under the Partnership’s unit repurchase program during 2013. Reef did not repurchase any units in 2012 or 2011. As a result, effective July 1, 2013, Reef also holds 0.19% of the 89% interest in the Partnership (0.17%) represented by these units. At December 31, 2013, Reef has a total interest in the Partnership of 15.62%.

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. Quarterly cash distributions to partners, if any, are based upon the number and type of partnership units held at the close of the prior quarter. Prior to September 30, 2013, cash distributions to partners of the net cash flow from interest income and crude oil and natural gas sales revenues, less operating and general and administrative costs were 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

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Reef Global Energy, VI, L.P.

Notes to Financial Statements (continued)

units) and 84.55% to investor partners. As a result of its repurchase of units during 2013, the managing general partner receives 0.17% of the 84.55% distributed to investor partners for all distributions, if any, paid subsequent to September 30, 2013.

Going Concern

The accompanying financial statements have been prepared assuming the Partnership is a going concern, which assumption contemplates the realization of assets and satisfaction of liabilities in the normal course of business.

The Partnership has had two significant producing properties. These two properties accounted for approximately 73.7% of total Partnership revenues during 2012, and 83.8% of total Partnership revenues during the six month period ended June 30, 2013. During the latter part of June one of these two wells ceased production, and two workover procedures performed on the well failed to restore production. As a result the well continues to be shut-in at December 31, 2013 and, after careful consideration, the Partnership has decided it will not participate in any future operations on this property. The Partnership is responsible for plugging and abandonment costs, unless the Partnership interest is assumed by third parties interested in attempting to return the well to productive status through additional drilling and workover procedures. The second significant property has an estimated remaining economic reserve life of 7 months, utilizing current prices, costs, and projected production volumes at December 31, 2013. This property accounted for 67.3% of total Partnership revenues during the last six months of 2013. The Partnership has no plans to drill additional wells. The Partnership also has no plans to engage in commodity futures trading or hedging activities. Finally, the estimated economic reserve life of Partnership wells is computed based upon operating revenues and costs and does not consider Partnership general and administrative costs. Future cash flows generated from Partnership wells will be significantly impacted by actual prices received subsequent to December 31, 2013, and by actual production volumes. Current projections indicate that subsequent to December 31, 2013, revenues generated from crude oil and natural gas sales will not be sufficient to cover operating expenses and general and administrative costs. These factors raise substantial doubt about the Partnership’s ability to continue as a going concern. The financial statements do not include any adjustments relating to the recoverability and classification of asset carrying amounts or the amount and classification of liabilities that might result should the Partnership be unable to continue as a going concern. The managing general partner is considering several options related to the Partnership, including the possible sale of marketable assets, as a result of the declining cash flows.

Reef, as the Partnership’s managing general partner and sole general partner, will be required to provide additional capital contributions to the Partnership should working capital and future cash generated from crude oil and natural gas sales not be sufficient to settle all remaining asset retirement obligations and pay operating and general and administrative costs. During 2013, Reef made a capital contribution totaling $100,000 to the Partnership. Reef will make additional capital contributions to cover Partnership obligations during 2014 if required.

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

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Reef Global Energy, VI, L.P.

Notes to Financial Statements (continued)

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.

Estimates of Proved Oil and Gas Reserves

Estimates of the Partnership’s proved reserves at December 31, 2013, 2012, and 2011 are prepared and presented in accordance with SEC rules and accounting standards which require SEC reporting entities to prepare their reserve estimates using the un-weighted arithmetic average of the first-day-of-the-month commodity prices over the preceding 12-month period and current 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 an independent petroleum engineering firm.

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.

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.

The Partnership has recognized an estimated liability for future plugging and abandonment costs. A liability for the

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Reef Global Energy, VI, L.P.

Notes to Financial Statements (continued)

estimated fair value of the future plugging and abandonment costs is recorded with a corresponding increase in the full cost pool at the time a new well is drilled or acquired. Depreciation expense associated with estimated plugging and abandonment costs is recognized in accordance with the full cost methodology.

The Partnership estimates a liability for plugging and abandonment costs based on historical experience and estimated well life. The liability is discounted using the credit-adjusted risk-free rate. Revisions to the liability could occur due to changes in well plugging and abandonment costs or well useful lives, or if federal or state regulators enact new well restoration requirements. The Partnership recognizes accretion expense in connection with the discounted liability over the remaining life of the well.

The following table summarizes the Partnership’s asset retirement obligation (inclusive of the current portion) for the years ended December 31, 2013 and 2012.

	2013			2012
Beginning asset retirement obligation	$	364,864		$	394,823
Accretion expense	18,632			63,766
Retirement related to sale of proved properties	(127,066		)	—
Retirement related to property abandonment and restoration	(938		)	(93,725		)
Ending asset retirement obligation	$	255,492		$	364,864

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, 2013, 2012, and 2011.

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, 2013, the tax basis of the Partnership’s assets exceeds the financial reporting basis of the assets by approximately $5.35 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

The Financial Accounting Standards Board (“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, and disclosure.

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, 2013 and 2012. The Partnership is subject to examination of income tax filings in the U.S. and various state jurisdictions for

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Reef Global Energy, VI, L.P.

Notes to Financial Statements (continued)

the years ended December 31, 2013 and 2012. The Partnership has not been subjected to any audits by the Internal Revenue Service for these periods.

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, accounts payable, and accounts payable to affiliates approximates their carrying value due to their short-term nature.

Comprehensive Income

Comprehensive income is defined as a change in equity of a business enterprise during a period from transactions and other events and circumstances from non-owner sources and includes all changes in equity during a period except those resulting from investments by owners and distributions to owners. The Partnership has no items of comprehensive income other than net income in any period presented. Therefore, net income as presented in the consolidated statements of operations equals comprehensive income.

Revisions to 2012 Financial Statements

During 2012, the Partnership incorrectly disclosed the allocation of total distributions paid. Distributions disclosed as paid to the managing general partner were understated by $16,865, while distributions disclosed as paid to the limited partners were overstated by the same amount. As a result of this error, the limited partner partnership equity was understated by $16,865 and the managing general partner partnership equity was overstated by $16,865 on the Partnership’s December 31, 2012 balance sheet. In addition, the distribution amount per partnership unit as shown on the Statement of Partnership Equity (Deficit) for December 31, 2012 was incorrect. The distribution amount per limited partner unit changed to $491.04, compared to the $502.81 previously reported. The distribution amount per managing general partner unit changed to $1,704.83, compared to the $1,481.05 previously reported. The changes to 2012 have been reflected on the Balance Sheet and Statement of Partnership Equity (Deficit) presented as a revision of the prior period amounts in this Annual Report on Form 10-K as the managing general partner does not believe these adjustments to be material to the financial statements taken as a whole.

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, 2013, 2012, and 2011 the Partnership incurred administrative costs totaling $61,811, $140,027, and $315,893, respectively. The Partnership incurred no technical services costs during the years ended December 31, 2013, 2012, and 2011. Administrative costs are included as general and administrative expenses on the statements of operations.

RELP processes joint interest billings and revenue payments on behalf of the Partnership. At December 31, 2013, the Partnership owed RELP $219,107 for joint interest and general and administrative charges processed in excess of net revenues. At December 31, 2012, RELP owed the Partnership $133,892 for net revenues processed in excess of joint interest and technical and administrative charges. The cash associated with net revenues processed by RELP is normally received by RELP from oil and gas purchasers 30-60 days after the end of the month to which the revenues pertain. The Partnership settles its balances with Reef and RELP on at least an annual basis. The Partnership paid RELP the December 31, 2013 balance due of $219,107 during February 2014.

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, 2013, 2012 and 2011, the Partnership paid operating overhead fees totaling $12,733, $21,431, and $20,609 to RELP.

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Reef Global Energy, VI, L.P.

Notes to Financial Statements (continued)

The Partnership reimbursed to Reef final legal fees totaling $25,000 during the year ended December 31, 2012 pertaining 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 the Partnership, and his claim involved his participation in these partnerships, including the Partnership. Pursuant to the Partnership Agreement of the Partnership, Reef is indemnified against litigation such as this, and the associated legal fees are to be reimbursed by the Partnership.

The Partnership reimbursed to Reef legal fees totaling $101,482 and $73,435, respectively, during the years ended December 31, 2013 and 2012 pertaining to the ongoing “Stevenson” litigation matter described in Note 5 below. The partners who brought the lawsuit are partners in several Reef affiliates, including the Partnership, and their claims involve their participation in these partnerships, including the Partnership. Pursuant to the Partnership Agreement of the Partnership, Reef is indemnified against litigation such as this, and the associated legal fees are being reimbursed to Reef by each of the partnerships involved on a quarterly basis.

4. Major Customers

5. Commitments and Contingencies

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Reef Global Energy, VI, L.P.

Notes to Financial Statements (continued)

filing their Sixth Amended Petition, Plaintiffs dismissed their claims for rescission under the TSA for failure of Defendants to register under the TSA, control person liability under the TSA in connection with such registration claims, and a majority of Plaintiffs’ fraud claims under the TSA. On December 18, 2012, the Court heard Defendants’ Joint Motion to Sever and Stay Claims of Plaintiff Jaimie Davis and to Sever Claims of Plaintiff Robert Phalen, and on that same date, the Court granted the Motion. Accordingly, Jaimie Davis’s claims have been severed and stayed, and are now pending under Cause of Action No. DC-13-00527 in the Dallas County District Court. Additionally, Robert Phalen’s claims have been severed and are now pending under Cause of Action No. DC-13-00528. As to the remaining Plaintiffs in the Stevenson matter, trial has been set for July 14, 2014. The Defendants intend to vigorously defend against these claims.

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 contributed $316,361 in connection with its obligation to pay 1% of all leasehold, drilling, and completion costs.

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 participated in the drilling of fifty-one wells and completed drilling operations with the capital raised by the Partnership in 2009.

Due to the net loss incurred during the year ended December 31, 2013, Partnership equity attributed to limited partnership interest has been reduced to zero. In accordance with the partnership agreement, limited partners’ capital accounts cannot be reduced to a deficit position. All losses in excess of this limitation are allocated to the managing general partner.

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Reef Global Energy, VI, L.P.

Notes to Financial Statements (continued)

As the managing general partner, Reef contributed cash of $100,000 during 2013 in order to allow the Partnership to make a partial settlement of its intercompany balance with RELP. In addition, Reef purchased 2.893 units of limited partner interest from non-Reef investor partners (“investor partners”) under the Partnership’s unit repurchase program during 2013.

As the managing general partner, Reef purchased 2.893 units of limited partner interest from investor partners under the Partnership’s unit repurchase program during 2013.

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.

7. Subsequent events

In early November 2013, following a second unsuccessful workover attempt to restore production from a shut-in Partnership well, the Partnership, after careful evaluation, decided not to participate in any future procedures the well operator might propose during 2014. The operator subsequently proposed to deepen the well, and the Partnership non-consented their proposal. During January 2014, the operator found third parties to assume the interest previously owned by the Partnership, and moved a rig onto the well with the intent to deepen the well. As a result of these operations, the Partnership no longer owns an interest in the well, and has been relieved of its obligation to plug and abandon the well. The Partnership removed its asset retirement obligation totaling $37,996 during the first quarter of 2014.

During the first quarter of 2014 RELP, as operator, plugged and abandoned a shut-in exploratory well in which the Partnership had a working interest.

During February 2014, the managing general partner made an additional capital contribution of $219,107 to the Partnership, which the Partnership used to settle its December 31, 2013 account payable with RELP.

8. 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,	2013			2012			2011

Oil and gas properties:
Proved properties	$	33,516,315		$	33,601,539		$	33,589,907
	33,516,315			33,601,539			33,589,907
Less:
Accumulated depreciation, depletion and amortization	(10,708,516		)	(10,557,490		)	(10,095,942		)
Property impairment	(22,741,225		)	(22,483,439		)	(22,241,674		)
Total	$	66,574		$	560,610		$	1,252,291

Costs Incurred

The following table sets forth costs incurred in oil and gas exploration and development activities during the years ended December 31, 2013, 2012, and 2011:

	2013			2012		2011

Oil and gas properties:
Exploration	$	—		$	11,632	$	150
Development	(3,997		)	—		15,120
Total	$	(3,997	)	$	11,632	$	15,270

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Reef Global Energy, VI, L.P.

Notes to Financial Statements (continued)

Results of Operations

The following table sets forth results of operations from oil and gas producing activities for the years ended December 31, 2013, 2012, and 2011:

	2013			2012			2011

Oil and gas producing activities:
Crude oil sales	$	346,824		$	1,019,151		$	2,619,211
Natural gas sales	141,043			460,931			1,189,909
Production expenses	(339,486		)	(437,973		)	(724,884		)
Accretion of asset retirement obligation	(18,632		)	(63,766		)	(15,300		)
Depreciation, depletion and amortization	(229,561		)	(367,822		)	(713,792		)
Property impairment expense	(257,785		)	(241,766		)	—
Results of producing activities	$	(357,597	)	$	368,755		$	2,355,144

Depletion rate per BOE	$	20.19		$	10.89		$	10.41

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 independent petroleum engineering firm Forrest A. Garb & Associates, Inc., as of December 31, 2013, 2012, and 2011. A copy of the Forrest A. Garb & Associates summary reserve report is included as Exhibit 99.1 to this Annual Report. 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, 2013, 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, 2013, 2012, and 2011.

	Oil (BBL) (1)		Gas (mcf)		BOE (2)
Net proved reserves for properties owned by the Partnership:
Reserves at December 31, 2010	48,860		792,380		180,293
Revisions of previous estimates	15,391		323,155		69,250
Production	(29,111	)	(236,655	)	(68,553	)
Reserves at December 31, 2011	35,140		878,880		181,620

Revisions of previous estimates	(19,054	)	(561,942	)	(112,712	)
Production	(12,106	)	(130,048	)	(33,780	)
Reserves at December 31, 2012	3,980		186,890		35,128

Reserves sold	(93	)	(214	)	(129	)
Revisions of previous estimates	2,619		(116,033	)	(16,720	)
Production	(4,686	)	(40,113	)	(11,371	)
Reserves at December 31, 2013	1,820		30,530		6,908

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Notes to Financial Statements (continued)

(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, 2013, 2012, and 2011, calculations were made using average prices of $96.90, $94.68, and $95.84 per barrel of crude oil, respectively, and $3.67, $2.76, and $4.15 per MCF of natural gas, respectively. 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.

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 the present worth of the properties. 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,	2013			2012			2011
Oil and gas properties owned by the Partnership:
Future cash inflows	$	339,350		$	1,199,610		$	8,912,250
Future production costs	(170,180		)	(539,020		)	(2,922,130		)
Future net cash flows	169,170			660,590			5,990,120
Effect of discounting net cash flows at 10%	(23,180		)	(99,980		)	(1,846,390		)
Discounted future net cash flows	$	145,990		$	560,610		$	4,143,730

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

December 31,	2013			2012			2011
Oil and gas properties owned by the Partnership:
Standardized measure at beginning of period	$	560,610		$	4,143,730		$	4,890,110
Extensions and discoveries				—			—
Net change in sales price, net of production costs	(70,551		)	(1,417,643		)	626,903
Revisions of quantity estimates	(353,327		)	(1,798,760		)	1,579,965
Net changes in estimated future development costs	—			—			—
Changes in production timing rates	83,996			197,253			(373,323		)
Accretion of discount	56,061			414,373			489,011
Sales net of production costs	(129,749		)	(978,343		)	(3,068,936		)
Sales of minerals in place	(1,050		)	—			—
Net increase (decrease)	(414,620		)	(3,583,120		)	(746,380		)
Standardized measure at end of year	$	145,990		$	560,610		$	4,143,730

F-15

Part I

Item 1.	Business
Item 1A.	Risk Factors
Item 1B.	Unresolved Staff Comments
Item 2.	Properties
Item 3.	Legal Proceedings
Item 4.	Mine Safety Disclosures

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

Date: March 27, 2014	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)

Signature	Title	Date

/s/ Michael J. Mauceli	Manager and Member of Reef Oil & Gas Partners, GP,	March 27, 2014
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	March 27, 2014
Daniel C. Sibley	Reef Exploration, L.P.
	(Principal Financial and Accounting Officer)

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 (deficit)	F-4
Statements of cash flows	F-5
Notes to financial statements	F-6