UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-K

(Mark One)

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

		For The Fiscal Year Ended December 31, 2007

or

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

For the Transition period from to

COMMISSION FILE NUMBER 333-122935-02

REEF GLOBAL ENERGY VII, L.P.

(Exact name of registrant as specified in its charter)

Nevada		20-3963203
(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 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 definition of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

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

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

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

As of March 31, 2008, the registrant had 48.620 units of general partner interest held by the managing general partner, 741.001 units of additional general partner interest and 182.783 units of limited partner interest outstanding.

Documents incorporated by reference: None

PART I

ITEM 1.

BUSINESS

Introduction

Reef Global Energy VII, L.P. (the Partnership) is the second 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 December 29, 2005. The Partnership purchases working interests in oil and natural gas prospects and participates in the drilling of wells on those prospects. The primary objectives of the Partnership are to generate revenue from the production of 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 natural gas wells located onshore in the continental United States. The Partnership purchased working interests in six developmental prospects located in Lavaca, San Patricio, and Glasscock County, Texas, Park County, Wyoming, Terrebonne Parish, Louisiana, and Eddy County, New Mexico upon which it has drilled twenty-one wells. The Partnership purchased working interests in seven exploratory prospects located in Iberville, St. Mary, and Cameron Parish, Louisiana, and Lavaca (2 prospects), San Patricio, and Galveston County, Texas upon which it has drilled seven exploratory wells and one developmental well. At December 31, 2007, twenty-five wells had completed drilling operations, and the remaining four wells completed drilling operations during the first quarter of 2008. The Partnership has no plans to purchase additional prospects. Additional wells may be drilled on the Partnership’s Sand Dunes prospect in Eddy County, New Mexico.

Other partnerships formed as a part of the Program also own working interests in some of the prospects owned by this Partnership. Reef has also purchased working interests in certain partnership prospects for some of the other partnerships it manages. In such cases where the percentage ownership of the Partnership and Reef-affiliated entities in a prospect has been large enough, Reef Exploration, L.P. (RELP) has served as operator of the prospect. RELP serves as operator of three developmental and two exploratory Partnership prospects. RELP operates eight successful wells located on one developmental prospect, operates one successful developmental well drilled on one of the Partnership’s exploratory prospects, and operates eight wells on the Partnership’s Sand Dunes developmental prospect, four of which are undergoing extended testing and evaluation in order to determine their potential commercial productivity, and four of which are temporarily shut-in due to the high cost associated with salt water disposal and generator rental. 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.

The attainment of the Partnership’s business objectives, including the generation of revenue from Partnership operations, the distribution of cash to the partners and the provision of tax benefits, will depend upon many factors, including:

·	Reef’s ability to select productive prospects;
·	the drilling and completion of wells in an economical manner;
·	the successful management of prospects;
·	the level of oil and natural gas prices in the future;
·	the degree of governmental regulation over the production and sale of oil and natural gas;
·	the future economic conditions in the United States and throughout the world; and
·	changes in the U.S. Internal Revenue Code of 1986 (the Code).

Accordingly, there can be no assurance that the Partnership will achieve its business objectives. In addition, distributions to partners will decrease over time because oil and natural gas wells are depleting assets, and production rates will decline over the life of an individual well. Distribution levels will also be highly dependent upon oil and natural gas prices. Distributions will be partially sheltered by the percentage depletion allowance.

Acquisition and Drilling of Undeveloped Prospects

The Partnership purchased working interests in three developmental and one exploratory prospect internally sourced by RELP, and three developmental and six exploratory prospects generated by and purchased from third parties. After the drilling of an unsuccessful exploratory well on one non-operated exploratory prospect, RELP took over as prospect operator and drilled a successful development well on the prospect. 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 development 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 development well, including wells drilled to find and produce oil or gas in an unproven area, wells drilled to find a new reservoir in a field previously found to be productive of oil or 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 of a prospect. 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’s limited partnership agreement (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. RELP serves as operator for three developmental and two exploratory prospects purchased by the Partnership.

Consulting Agreements for Prospect Acquisitions

Reef entered into, and allowed to expire, two agreements (the CMI Agreements) with Challenger Minerals Inc. (CMI), a subsidiary of GlobalSantaFe Corporation and a screener of oil and gas prospects in the Gulf of Mexico and North Sea regions. The CMI Agreements provided Reef the opportunity to review and selectively participate in exploratory and developmental prospects either originated or previewed by CMI. Reef paid CMI for the geological and geophysical services provided by CMI under the CMI agreements. The agreements expired in January and November, 2006.

Reef also entered into an agreement with Access Exploration Corp. (AEC), a screener of domestic oil and gas prospects both onshore and in the Gulf of Mexico. This agreement provided Reef the opportunity to review and selectively participate in exploratory and developmental prospects previewed by AEC. Reef paid AEC for the geological and geophysical services provided by AEC under this agreement. This agreement expired in October 2007.

Prospects approved for acquisition by Reef under these agreements could be assigned to this Partnership as well as other limited partnerships formed as part of the Program. Each partnership formed as a part of the Program paid Reef, on a pro rata basis, a portion of the fees paid by Reef under these agreements during the term of the Program. Total reimbursements to Reef by the partnerships formed as a part of this Program were equal to the actual fees paid by Reef under these agreements. The Partnership paid Reef $150,736 as its pro rata share of these fees. This amount has been capitalized as geological and geophysical costs in accordance with the full cost method of accounting for oil and gas properties.

Drilling and Completion Phase of Operations

RELP is currently the operator of three developmental and two exploratory prospects, and serves as operator of seventeen wells in which the Partnership has a working interest. RELP also served as operator for two unsuccessful Partnership wells. 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.

RELP contracted the drilling of all operated wells to an independent third party, and the resulting costs of the wells to the Partnership were determined by the actual third party costs, plus RELP’s monthly charges for supervision, engineering, geology, accounting and other services at the competitive rate for the geographical area where the well is located.

Wells drilled that fail to result in the discovery of oil or natural gas, or that are determined to be unable to produce oil or natural gas in commercial quantities, are plugged and abandoned in accordance with applicable regulations.

Of the eight Sand Dunes prospect wells, four wells are undergoing extended testing and evaluation in order to determine their potential commercial productivity. The Partnership estimates that it may take between 90 and 120 days from the date of this Annual Report to finish the evaluation process. Following initial testing which confirmed the presence of oil and natural gas, the remaining four Sand Dunes prospect wells were temporarily shut in due to the high cost associated with salt water disposal and generator rental.

Currently, generators have been rented to power the four producing Sand Dunes prospect wells undergoing the evaluation process, and salt water produced is being trucked off-site by an independent vendor. In order to reduce overall costs, installation of electric service to the well-site locations is proceeding, and a more cost effective method of salt water disposal is being explored. To date, RELP, the operator of these wells, has been unsuccessful in locating a long-term economic solution for disposing of produced salt water; however, RELP is currently evaluating its options for salt water disposal, and estimates that it will be at least 90 to 120 days from the date of this Annual Report for the Sand Dunes prospect to have electricity and efficient salt water disposal capability in place.

Production Phase of Operations

For any well capable of producing quantities of oil and/or natural gas in commercial quantities, production operations commence once the well has been 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 oil and/or natural gas production from the well. The Partnership drilled ten successful developmental wells and one successful exploratory well. The successful exploratory well has ceased producing during 2007. Three developmental and six exploratory wells were dry holes and have been plugged and abandoned. One additional successful developmental well finished drilling during the first quarter of 2008 and is expected to begin production during the second quarter of 2008.

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

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

The Partnership has not engaged in and does not expect to engage 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. See “Item 7A. Quantitative and Qualitative Disclosures 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, 2007, two marketers accounted for 79.4% and 16.5% of the Partnership’s oil and natural gas revenues, respectively. As of December 31, 2006 and 2005, the Partnership had no oil and natural gas production and, therefore, had no customers. Due to the competitive nature of the market for purchase of crude oil and natural gas, the Partnership does not believe that the loss of any particular purchaser would have a material adverse impact on the Partnership.

Insurance

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

The Partnership is a named insured under various insurance policies and intends to maintain such policies subject to its analysis of their premium costs, coverage and other factors. In the exercise of Reef ‘s fiduciary duty as managing general partner, Reef has obtained insurance on behalf of the Partnership to provide the Partnership with such coverage as Reef believes is sufficient to protect the partners other than the managing general partner (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.

Reef will notify all investor general partners of the Partnership at least 30 days prior to any material change in the amount of the Partnership’s insurance coverage. Within this 30-day period and otherwise after the expiration of one year following the closing of the offering of the Partnership, investor general partners have the right to convert their units into units of limited partnership interest by giving Reef written notice of their intent to convert. At any time during this 30-day period, upon receipt of the required written notice from an investor general partner of his intent to convert, Reef will amend the Certificate of Limited Partnership of the Partnership and will file the amendment with the State of Nevada prior to the effective date of the change in insurance coverage. This amendment to the Certificate of Limited Partnership of the Partnership will effectuate the conversion of the interest of the former investor general partner to that of a limited partner. Effecting conversion is subject to the express requirement that the conversion will not cause a termination of the Partnership for federal income tax purposes. Investor general partners will have limited liability as a limited partner for any Partnership operations conducted after their conversion date, effective upon the filing of an amendment to the Certificate of Limited Partnership of the Partnership. However, even after an election of conversion, the investor partner will continue to have unlimited liability regarding partnership activities that occurred while he was an investor general partner.

Competition

There are thousands of oil and natural gas companies in the United States. Competition is strong among persons and entities involved in the exploration for and production of 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.

There is competition among operators for drilling equipment, goods, and drilling crews. Such competition may affect the ability of the Partnership to develop prospects suitable for development by the Partnership once they are acquired.

Markets

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

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

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

Production. In most areas of operations within the United States the production of oil and natural gas is regulated by state agencies that set allowable rates of production and otherwise control the conduct of oil and natural gas operations. Among the ways that states control production is through regulations that establish the spacing of wells or limit the number of days in a given month during which a well can produce.

Environmental. 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.

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 gas. Such deregulated 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 gas produced by the Partnership’s wells will be considered price-decontrolled gas and that the Partnership’s gas will be sold at fair market value.

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 natural 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. Through January 1, 2006, OREI Inc. (OREI), an affiliate of Reef, employed a staff including geologists, petroleum engineers, landmen, and accounting personnel who administered all of the Partnership’s operations. On January 2, 2006, the employees of OREI were transferred to RELP, a new Reef affiliate formed during 2005. RELP now employs this staff of geologists, geophysicists, petroleum engineers, landmen and accounting personnel who administer all of the Partnership’s operations. The Partnership reimburses OREI and RELP for technical and administrative services at cost. See “Item 11. Executive Compensation.”

FORWARD-LOOKING STATEMENTS

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

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

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 natural gas properties depend primarily upon the prices received for our oil and natural gas production. 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 oil and natural gas production. The prices for oil and natural gas are subject to a variety of factors beyond our control. These factors include:

·		the domestic and foreign supply of oil and natural gas; consumer demand for oil and gas, and market expectations regarding supply and demand;
·		the ability of the members of OPEC to agree to and maintain 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 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, oil and natural gas prices do not necessarily move in tandem. Declines in oil and natural gas prices would not only reduce revenues and cash flow available for distributions to partners, but could reduce the amount of 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, oil and gas reserves, and the carrying value of the Partnership’s oil and natural gas properties. Approximately 43.5% of the Partnership’s estimated proved reserves were oil reserves and 56.5% were gas reserves at December 31, 2007. As a result, the Partnership’s financial results are sensitive to fluctuations in both oil and 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 oil and natural gas, has not engaged in such activities. Accordingly, the Partnership is at risk for the volatility in oil and natural gas prices, and the level of commodity prices has a significant impact upon the Partnership’s results of operations.

Oil and natural gas well drilling is a speculative activity involving numerous risks and substantial and uncertain costs which could adversely affect the Partnership.

Drilling oil and natural gas wells involves numerous risks, including the risk that no commercially productive oil and/or natural gas reserves will be discovered. There can be no assurance that wells drilled by the Partnership will be productive or recover all or any portion of the investment in such wells. Drilling and completion costs are substantial and uncertain, and drilling operations may be curtailed, delayed, or cancelled due to a variety of factors beyond our control, including shortages or delays in the availability of drilling rigs and crews, unexpected drilling conditions, title problems, pressure or irregularities in formations, equipment failures or accidents, adverse weather conditions, and compliance with environmental and other governmental regulations. Our drilling activities may not be successful and, if unsuccessful, will have an adverse effect on the Partnership’s results of operations and cash flow available for distribution to the partners.

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 natural gas wells, including blowouts involving possible damages to property and third parties, bodily injuries, mechanical failures, explosions, uncontrollable flows of 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.

Continued inability to dispose of produced salt water may limit production on our oil and natural gas properties.

Currently, the Partnership does not have an economically efficient manner in which to dispose of the salt water produced from the eight Sand Dunes prospect wells. The Partnership anticipates it will be at least 90 to 120 days from the date of this Annual Report for the Sand Dunes prospect to have efficient salt water disposal capabilities in place. The Partnership will be unable to obtain full production from each well until a long-term economic solution for the disposing of produced salt water is determined and implemented. If the Sand Dunes prospect wells are determined capable of producing in commercial quantities prior to implementation of such long-term economic solution, there will be significant delays in obtaining full production from each well, as well as significant delays in the receipt of production distributions by the investor partners.

We cannot control activities on non-operated properties.

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

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

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

Oil and natural gas reserve data are estimates based upon assumptions that may be inaccurate and upon 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 and inexact process of estimating underground accumulations of 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.

You should not assume that any present value of future net cash flows from our producing reserves shown in this Annual Report is the market value for our estimated oil and natural gas reserves. The estimated discounted future net cash flows from our proved reserves are based upon prices and costs in effect at the end of the period held constant and discounted at 10%. Actual 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 development expenditures, the rate and timing of production, and changes in governmental regulations and tax rates.

Reef and its affiliates have sponsored ventures in the past that have produced dry holes and abandoned wells.

Reef Global Energy Ventures II is the second public drilling program sponsored by Reef as the managing general partner, and Reef Global Energy VII, L.P. is the second limited partnership offered under that Program. Reef and its affiliate OREI have sponsored 68 ventures from 1996 to the present. Among these ventures, (i) eight were dedicated almost exclusively to the purchase of interests in already producing reserves, (ii) one was dedicated primarily to the purchase of interests in already producing reserves but has the ability to use up to 20% of capital raised for development purposes, and (iii) three were dedicated to both the purchase of interests in producing wells and the use of up to 50% of capital raised for development of proven reserves. We refer to the programs described in clause (i) in the preceding sentence as “income fund” ventures and to the programs described in clauses (ii) and (iii) as “income and development fund” ventures. Reef and its affiliates have also sponsored 52 drilling ventures, three 3-D seismic ventures, and one salt water disposal venture since 1996. Together, these ventures have drilled 132 wells (104 by drilling ventures and 28 by income fund and income and development fund ventures). Of the wells drilled by Reef and its affiliates’ ventures, 63 were exploratory wells and 69 were developmental wells. Forty-nine of the wells drilled were dry holes, and three wells were completed but were non-commercial. Of the 80 wells that were commercial, 60 are still owned by Reef or its affiliates’ ventures and are currently producing, eighteen have been plugged and abandoned or sold essentially for salvage value, one has been sold, and one is currently used as a salt water disposal well. Using this data, approximately 60.6% of the wells drilled by these ventures were completed as commercially producing and 39.4% were dry holes (including the three wells that were completed but failed to become commercial producers). Approximately 13.6% of the wells drilled by our ventures were subsequently abandoned or sold essentially for salvage value prior to abandonment.

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.

Drilling exploratory wells is riskier than drilling developmental wells.

Many of the wells drilled by Reef and its affiliates since 1996 have been exploratory wells. Drilling exploratory wells involves greater risks of dry holes and loss of the partners’ investment than the drilling of developmental wells. Drilling developmental wells generally involves less risk of dry holes, although sometimes developmental acreage is more expensive and subject to greater royalties and other burdens on production. The Partnership purchased working interests in seven exploratory prospects upon which seven exploratory and one developmental well were drilled. Six exploratory wells were unsuccessful, and one exploratory well was successful but has ceased production as of December 31, 2007. The developmental well was successful and is currently producing oil and natural gas.

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 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 natural gas wells, if any, will decline over time, and does not indicate any consistent level of future production. This production decline may be rapid and irregular when compared to a well’s initial production.

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

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

Our dependence on third parties for the processing and transportation of oil and 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 oil and 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.

High demand for drilling contractors, field services and equipment, and the ability of suppliers to meet demand may limit our ability to drill and produce our oil and natural gas properties.

Due to current industry demands, drilling contractors, well service providers and related equipment and personnel are in short supply. This is causing escalating prices, delays in drilling and other exploration activities, and the possibility of poor service coupled with potential damage to downhole reservoirs and personnel injuries. Such pressures will likely increase the actual cost of services, extend the time to secure such services, and add costs for damages due to any accidents sustained from overuse of equipment and inexperienced personnel.

We face strong competition within the energy industry.

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

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

The Partnership intends to utilize substantially all available capital for the drilling and completion of wells and acquisition of the prospects. The Partnership only has nominal funds available for partnership purposes until there are revenues from Partnership operations. The Partnership Agreement permits the Partnership to borrow money for future development of prospects drilled by the Partnership with the original available Partnership capital. Any future requirement for additional funding will have to come, if at all, from the Partnership’s revenues or from borrowings. Reef cannot assure the partners that Partnership operations will be sufficient to provide the Partnership with necessary additional funding. Reef cannot assure the partners that the Partnership will be able to borrow funds from third parties on commercially reasonable terms or at all.

The Partnership may be required to pay delay rentals to hold properties, which may deplete Partnership capital.

Oil and gas leases generally require that the property must be drilled upon by a certain date or additional funds known as delay rentals must be paid to keep the lease in effect. Delay rentals typically must be paid within a year of the entry into the lease if no production or drilling activity has commenced. If delay rentals become due on any property the Partnership acquires, the Partnership will have to pay its share of such delay rentals or lose its lease on the property. These delay rentals could equal or exceed the cost of the property. Further, payment of these delay rentals could seriously deplete the Partnership’s capital available to fund drilling activities when they do commence.

The Partnership may incur liability for liens against its subcontractors.

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

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

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

ITEM 1B.

UNRESOLVED STAFF COMMENTS

None.

ITEM 2.

PROPERTIES

Drilling Activities and Productive Wells

Partnership prospects are located onshore in Texas, Louisiana, New Mexico, and Wyoming. The Partnership purchased working interests in six developmental prospects. The Partnership drilled nine successful developmental wells on two developmental prospects located in Glasscock County, Texas (8 wells) and Park County, Wyoming. The Partnership drilled one successful and one unsuccessful developmental well on a prospect located in Terrebonne Parish, Louisiana, and drilled two unsuccessful developmental wells on two developmental prospects located in Lavaca and San Patricio County, Texas.

The Partnership has participated in the drilling of eight developmental wells on the Sand Dunes developmental prospect in Eddy County, New Mexico. Of the eight Sand Dunes prospect wells, four wells are undergoing extended testing and evaluation in order to determine their potential commercial productivity. The Partnership estimates that it may take between 90 and 120 days from the date of this Annual Report to finish the evaluation process. Following initial testing which confirmed the presence of oil and natural gas, the remaining four Sand Dunes prospect wells were temporarily shut in due to the high cost associated with salt water disposal and generator rental.

The Partnership purchased working interests in seven exploratory prospects, upon which one successful exploratory well, one successful developmental well, and six unsuccessful exploratory wells have been drilled. The successful exploratory well in San Patricio, County has ceased production as of December 31, 2007. The Partnership drilled one unsuccessful exploratory well and one successful developmental well on a prospect located in Galveston County, Texas. The Partnership also drilled five unsuccessful exploratory wells on five exploratory prospects located in Lavaca (2 prospects) County, Texas and Iberville, St. Mary, and Cameron Parish, Louisiana.

The unproved properties owned by the Partnership at December 31, 2007 consist of un-drilled leasehold interests (11 potential drilling locations) in the Sand Dunes prospect. The Partnership does not have available capital to drill these potential locations. The Partnership may sell all or a part of these leasehold interests to third parties or other Partnerships managed by Reef. Alternatively, the Partnership is permitted to borrow funds or utilize cash flows from existing productive properties in order to conduct future developmental drilling on this prospect. Partner approval would not need to be obtained for borrowing activity, as the estimated additional cost is not in excess of 25% of the Partnership’s original aggregate capital contributions. Until such time as the productive capability of the eight wells already drilled can be fully analyzed (see Note 8 to the Partnership’s financial statements), it is unknown whether the Partnership will drill additional wells on the Sand Dunes prospect or sell all or a portion of the acreage. The estimated cost to the Partnership of participating in future drilling operations at its current working interest ownership is approximately $169,000-$225,000 per location.

The Partnership currently has ten successful productive wells, one successful well that has ceased production, one successful well which is expected to begin production during the second quarter of 2008, and is continuing its extended testing and evaluation of four Sand Dunes wells. The remaining four Sand Dunes prospect wells are temporarily shut-in due to the high cost associated with salt water disposal and generator rental.

Proved Oil and Gas Reserves

The Partnership uses an independent petroleum engineer to prepare its year end estimate of net proved oil and natural gas reserves. Net proved oil and natural gas reserves as of December 31, 2007 have been estimated by Gleason Engineering, of Arlington, Texas. The quantities of proved oil and gas reserves discussed in this section include only the amounts which we reasonably expect to recover in the future from known oil and gas reservoirs under the current economic and operating conditions. Proved reserves include only quantities that we expect 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. The Partnership had no proved reserves at December 31, 2006 and 2005. The estimated net proved oil and natural gas reserves at December 31, 2007 are summarized below.

		Oil (BBL)		Gas (MCF)
Net proved reserves as of December 31, 2007		96,871		755,717

The standardized measure of discounted future net cash flows as of December 31, 2007 is computed by applying year-end prices, costs, and legislated tax rates and a discount factor of 10% to net proved reserves. The standardized measure of discounted future net cash flows does not purport to present the fair value of our oil and natural gas reserves.

Standardized measure of discounted future net cash flows as of December 31, 2007

7,199,362

During the years ended December 31, 2007 and 2006, the Partnership recorded property impairment costs totaling $10,739,537 and $1,825,482 as a result of the net capitalized costs of oil and gas properties exceeding the standardized measure of discounted future net cash flows.

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

The Partnership is not, and has not been, a party to any legal proceedings.

ITEM 4.

SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS

None.

PART II

ITEM 5.

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

As of December 31, 2007, the Partnership had one managing general partner, 173 limited partners, and 709 additional general partners. Reef holds a total of 48.620 general partner units and the investor partners hold 741.001 general partner units and 182.783 limited partner units. No established trading market exists for the units.

Cash which, in the sole judgment of the managing general partner, is not required to meet the Partnership’s obligations is distributed to the partners at least quarterly in accordance with the Partnership Agreement. The Partnership began making monthly cash distributions to the partners of interest income and net oil and natural gas revenues in August 2006. Cash distributions are distributed 15.45% to the managing general partner (based upon the 11% interest not represented by units and the 4.45% interest represented by Partnership units) and 84.55% to investor partners.

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

The Partnership has adopted a unit repurchase program. Under the terms of the program, the managing general partner is obligated to purchase up to 5% of the units in the Partnership per year in the sixth through tenth years after the Partnership closes unless changes in oil and gas pricing meet certain criteria specified in the prospectus supplement, dated November 15, 2005. However, the managing general partner’s obligation to purchase units is limited to $500,000 per year in the aggregate for all partnerships previously or subsequently organized by the managing general partner or its affiliates. The Partnership did not repurchase any units in 2007.

Use of Proceeds

In connection with the Registration Statement filed on form S-1 (No. 333-122935) and declared effective July 7, 2005, Reef filed a final prospectus for the Program on July 8, 2005. On November 15, 2005, Reef filed a prospectus supplement describing the Partnership and commenced the offering of units in the Partnership. All sales of Partnership units were made through the Program’s dealer-manager, Reef Securities, Inc., and a number of soliciting dealers. The offering terminated April 28, 2006. Under the terms of the offering, a minimum of 40 Partnership units at a price of $25,000 per unit were required to be sold in order to form the Partnership. Upon meeting this requirement, the Partnership was formed on December 29, 2005.

The Partnership registered a total of 240 units of limited partner interests and 960 units of general partner interests. The aggregate offering amount registered was $30,000,000. During the offering period that terminated on April 28, 2006, the Partnership sold 923.784 units to investor partners, consisting of 182.783 units of limited partner interest and 741.001 units of additional general partner interest. Reef purchased 48.620 general partner units, equaling 5.00% of the total Partnership units sold. The Partnership did not sell the remaining registered units. Total offering proceeds were $24,127,769. Reef also is obligated to contribute 1% of all leasehold, drilling, and completion costs as incurred. At December 31, 2007, Reef had contributed $182,815 and accrued $10,969 as a payable to the Partnership in connection with this obligation.

All units except those purchased by Reef paid a 15% management fee to Reef to pay for the Partnership organization and offering costs, including sales commissions. These costs totaled $3,464,188, leaving capital contributions of $20,857,365 available for Partnership oil and gas operations. As of December 31, 2007, the Partnership had expended $20,867,467 on property acquisitions and prepayments and $137,516 on general and administrative expenses. The Partnership will expend additional funds on the drilling and completion of four wells during the first and second quarters of 2008, and may expend funds on salt water disposal facilities for the wells located on the Sand Dunes prospect. Expenditures in excess of available capital will be deducted from Partnership distributions during 2008.

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.

	Year ended December 31, 2007			Year ended December 31, 2006			Period from Inception (December 29, 2005) to December 31 2005

Oil and gas sales revenue	$	1,517,970		$	—		$	—
Interest income	317,661			691,667			1,212
Costs and expenses	(12,187,144		)	(1,894,563		)	(50,475		)
Partnership net loss	(10,351,513		)	(1,202,896		)	(49,263		)

Allocation of net loss:
Managing general partner	(476,894		)	(12,240		)	(73		)
General partner units	(7,920,794		)	(956,084		)	(38,450		)
Limited partner units	(1,953,825		)	(234,572		)	(10,740		)
Net loss per managing partner unit	(9,808.55		)	(251.74		)	(20.58		)

	Year ended December 31, 2007			Year ended December 31, 2006			Period from Inception (December 29, 2005) to December 31 2005

Net loss per general partner unit	(10,689.32		)	(1,290.26		)	(729.60		)
Net loss per limited partner unit	(10,689.32		)	(1,283.33		)	(719.23		)

Total assets	8,620,722			21,786,620			1,594,304
Distributions to managing general partner	238,316			45,578			—
Distributions to investor partners	1,304,184			249,422			—
Distributions per general partner unit	1,411.78			270.00			—
Distributions per limited partner unit	1,411.78			270.00			—
Distributions per managing general partner unit	4,901.60			937.43			—

Operating Data
Annual sales volume:
Gas (MCF)	48,301			—			—
Oil (BBL)	14,032			—			—

Average sales price:
Gas (per MCF)	$	8.59		$	—		$	—
Oil (per BBL)	$	78.60		$	—		$	—

ITEM 7.

MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

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

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

Critical Accounting Policies

The preparation of financial statements in conformity with accounting principles generally accepted in the United States 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 crude oil and natural 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 crude oil and natural gas properties and estimated future development costs, excluding unproved properties, are based on the unit-of-production method using estimated proved reserves. Proved gas reserves are converted to equivalent barrels at a rate of 6 Mcf to 1 Bbl. Net capitalized costs of crude oil and natural gas properties, as adjusted for asset retirement obligations, are limited to the lower of unamortized cost or the cost ceiling, defined as the sum of the present value of estimated future net revenues from proved reserves based on prices in effect at the end of the period held constant and discounted at 10 percent, plus the lower of cost or estimated fair value of unproved properties, if any. Pursuant to full cost accounting rules, the Partnership performs a ceiling test quarterly as of the balance sheet date on its proved oil and natural gas properties. Excess capitalized costs are charged to property impairment expense. No gain or loss is recognized upon sale or disposition of crude oil and natural gas properties, unless such a sale would significantly alter the rate of depletion and amortization. During the years ended December 31, 2007 and 2006, the Partnership recognized property impairment expense of proved properties totaling $10,739,537 and $1,825,482, respectively.

Overview

Reef Global Energy VII, 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 oil and gas, distribute cash flow to investors, and provide tax benefits to investors. The majority of the Partnership’s proceeds will be used to purchase prospects and drill oil and natural gas wells upon those prospects.

The Partnership raised capital from the sale of Partnership units to investor partners and Reef, and uses those funds for the purchase of working interests in prospects and for drilling 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 oil and gas revenues from successful wells, net of expenses, are being 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 drill additional development wells and construct facilities on prospects where successful wells were drilled during the drilling phase of operations. The Partnership completed its drilling phase of operations during the first quarter of 2008.

The Partnership does not operate in any other industry segment. The Partnership has expended approximately $1,949,000 for the purchase of working interests in six developmental prospects, which includes approximately $172,500 for 11 un-drilled locations on its Sand Dunes prospect, and expended approximately $605,000 for the purchase of working interests in seven exploratory prospects. The Partnership has seven prospects in Texas, four in Louisiana, one in Wyoming, and one in New Mexico, all of which are located onshore. The Partnership has drilled twenty-two developmental and seven exploratory wells on these prospects, three of which were drilled during 2006, twenty-two of which were drilled during 2007, and four of which completed drilling during the first quarter of 2008. The Partnership currently has eleven successful developmental wells, ten of which are currently productive and one expected to begin production activity during the second quarter of 2008, and three unsuccessful developmental wells. The Partnership drilled one successful exploratory well and six unsuccessful exploratory wells. The successful exploratory well has ceased production. The Partnership also has participated in the drilling of eight wells on its Sand Dunes prospect. Of the eight Sand Dunes prospect wells, four wells are undergoing extended testing and evaluation in order to determine their potential commercial productivity. The Partnership estimates that it may take between 90 and 120 days from the date of this Annual Report to finish the evaluation process. Following initial testing which confirmed the presence of oil and natural gas, the remaining four Sand Dunes prospect wells were temporarily shut in due to the high cost associated with salt water disposal and generator rental. Up to 11 additional wells may be drilled on the Sand Dunes prospect.

Should the Partnership elect to borrow monies for additional development activity on the Sand Dunes prospect, it will be subject to the interest rate risk inherent in borrowing activities. The Partnership is permitted but is not expected to engage in commodity futures trading or hedging activities, and therefore is subject to commodity price risk. See “Item 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.”

During the fourth quarter of 2007, the Partnership completed drilling one unsuccessful developmental well. At December 31, drilling operations were in progress on the sidetracking of a Partnership developmental well that was unsuccessful earlier in 2007. The sidetracking operations were successfully completed during February 2008, and the well is currently being completed and expected to begin production during the second quarter of 2008. The Partnership completed drilling operations on five Sand Dunes prospect wells during the fourth quarter, and drilling operations that were in progress on three additional Sand Dunes wells at December 31, 2007 were completed during the first quarter of 2008.

Liquidity and Capital Resources

The Partnership was funded with initial capital contributions totaling $24,127,769. Reef purchased 48.620 general partner units, or 5% of the total units sold, for $1,033,179. Investor partners purchased 741.001 general partner units and 182.783 limited partner units for $23,094,590. As of December 31, 2007, Reef has also contributed $182,815 and accrued $10,969 in connection with its obligation to pay 1% of all leasehold, drilling, and completion costs. Organization and offering costs totaled $3,464,188, leaving capital contributions of $20,857,365 available for Partnership activities. The Partnership was formed on December 29, 2005, and the last partner was admitted to the Partnership on April 28, 2006.

The $20,857,365, plus any additional contributions made by Reef in connection with the 1% obligation mentioned above, is the total amount available to the Partnership for the purchase of prospects and for drilling and administrative costs. As of December 31, 2007, the Partnership had expended $20,867,467 on property acquisitions and prepayments and $137,516 on general and administrative expenses. The Partnership will expend additional funds on the drilling and completion of four wells during the first and second quarters of 2008, and will also expend funds on salt water disposal facilities for the wells located on the Partnership’s Sand Dunes prospect during 2008. Expenditures in excess of available capital will be deducted from Partnership distributions during 2008.

Please see Item 1A of this Annual Report for a list of risk factors that could impact the Partnership.

The table below summarizes Partnership drilling expenditures during the drilling phase of operations by type and classification of well:

	Leasehold Costs		Drilling, Completion, and Facilities Costs		Total Costs
Developmental wells	$	1,948,957	$	11,756,615	$	13,705,572
Exploratory wells	605,200		6,556,695		7,161,895
Total	$	2,554,157	$	18,313,310	$	20,867,467

Successful wells	$	1,538,536	$	9,110,969	$	10,649,505
Unsuccessful wells	717,574		7,809,523		8,527,097
Wells under development	125,600		1,392,818		1,518,418
Unproved properties	172,447		—		172,447
Total	$	2,554,157	$	18,313,310	$	20,867,467

The Partnership had working capital of $673,856 at December 31, 2007, which includes interest income and net revenues available for distribution to partners, and $430,096 of deferred organization and offering costs.

The unproved properties owned by the Partnership at December 31, 2007 consist of un-drilled leasehold interests (11 potential drilling locations) in the Sand Dunes prospect. The Partnership does not have available capital to drill these potential locations. The Partnership may sell all or a part of these leasehold interests to third parties or other Partnerships managed by Reef. However, the Partnership is permitted to borrow funds or utilize cash flows from existing productive properties in order to conduct future developmental drilling on this prospect. Partner approval would not need to be obtained for borrowing activity, as the estimated additional cost is not in excess of 25% of the Partnership’s original aggregate capital contributions. Until such time as the productive capability of the eight wells already drilled can be fully analyzed (see Note 9 to the Partnership’s financial statements), it is unknown whether the Partnership will drill additional wells on the Sand Dunes prospect or sell all or a portion of the acreage. The estimated cost to the Partnership of participating in future drilling operations at its current working interest ownership is approximately $169,000-$225,000 per location.

The Partnership will expend more than its available capital in connection with the twenty-nine wells that had been drilled or were drilling at December 31, 2007. Expenditures in excess of available capital will be deducted from Partnership distributions during 2008.

Results of Operations

Year ended December 31, 2007 compared to Year Ended December 31, 2006

During 2007, the Partnership incurred a net loss of $10,351,513, compared to a net loss of $1,202,896 incurred during 2006.

During 2006, the Partnership drilled three wells, all of which were unsuccessful. The Partnership had no oil and natural gas revenues from productive wells. The Partnership had interest income earned from the short-term investment of unexpended partner capital of $691,667, offset by $69,081 of general and administrative costs and $1,825,482 of property impairment cost, which resulted in a net loss of $1,202,896.

During 2007, the Partnership drilled eleven successful wells, ten of which are productive as of December 31, 2007. The first productive well of the Partnership began operations in March 2007. Six wells began production operations during the second quarter of 2007, and four wells began production operations during the third quarter of 2007. The Partnership also has participated in the drilling of eight wells on its Sand Dunes prospect, three of which completed drilling operations during the first quarter of 2008. Of the eight Sand Dunes prospect wells, four wells are undergoing extended testing and evaluation in order to determine their potential commercial productivity. The Partnership estimates that it may take between 90 and 120 days from the date of this Annual Report to finish the testing and evaluation process. Following initial short-term tests which confirmed the presence of oil and natural gas, the remaining four Sand Dunes prospect wells were temporarily shut in due to the high cost associated with salt water disposal and generator rental.

Oil and natural gas sales revenues and barrels of oil equivalent (BOE) sold by quarter are detailed below. The Partnership had no comparative oil and natural gas sales revenue for 2006, as all three wells drilled by the Partnership during 2006 were unsuccessful.

	1^st Quarter		2^nd Quarter		3^rd Quarter		4^th Quarter
2007 Oil and Natural Gas Sales Revenues	$	9,579	$	147,135	$	635,516	$	725,740

Barrels of Oil Equivalent (BOE) Sold *	178		2,359		9,344		10,201

* BOE (Barrels of oil equivalent (6 MCF of natural gas equals 1 BOE)

Production expenses totaled $231,989 during the year ended December 31, 2007, and are detailed on both an overall and a BOE basis by quarter below. There were no comparable expenses during 2006.

	1^st Quarter		2^nd Quarter		3^rd Quarter		4^th Quarter
2007 Production expenses	$	1,556	$	25,362	$	86,054	$	119,017

Production expenses per BOE	$	8.74	$	10.75	$	9.21	$	11.67

The increase in production expenses on a BOE basis during the fourth quarter of 2007 relates directly to the eight wells on the Partnership’s Cole Ranch prospect. Oil and natural gas sales revenues from these eight wells declined by 16.8% during the fourth quarter of 2007 to $499,274, as compared to $599,788 during the third quarter, while production expenses increased from $82,723 to $96,344. The Partnership reduced the estimated reserves it expects to recover from the Cole Ranch prospect wells in the third quarter of 2007 because peak production from the wells was less than originally anticipated. However, this reduction was offset by reserves from new discoveries during the third quarter, and the Partnership recorded no property impairment expense during the third quarter of 2007. The declining production rates and increasing production expenses during the fourth quarter have led to additional reductions in the estimated recoverable reserves from these eight wells. Combined with the unsuccessful development well drilled during the fourth quarter, these two items have caused the Partnership to record property impairment expense totaling $6,315,241 during the fourth quarter. The Partnership had earlier recorded property impairment expense totaling $4,424,296 during the first two quarters of 2007 as a result of four unsuccessful wells, for a total 2007 property impairment expense of $10,739,537. The Partnership recorded property impairment expense totaling $1,825,482 during 2006 because all three wells completed during 2006 were unsuccessful.

General and administrative costs totaled $135,603 during 2007 as compared to $69,081during 2006. Administrative costs paid to Reef rose from $5,203 to $57,221, accounting for a substantial portion of the increase. These costs were directly related to the Partnership well count increasing from three wells during 2006 to twenty-nine wells during 2007. Legal, accounting, and printing costs related to the Partnership’s required SEC filings rose from $59,792 in 2006 to $74,912 during 2007.

The property impairment expense of $10,739,537 was the primary factor in the net loss of $10,351,513 for 2007.

Year Ended December 31, 2006 compared to the Period from Inception (December 29, 2005) thru December 31, 2005

The Partnership began operations in December 2005. The 2005 net loss of $49,263 shown in the financial statements represents a charge of $50,000 for organization expenses and $475 for other general and administrative expenses, offset by interest income of $1,212 earned from the short-term investment of partner capital contributions. The Partnership did not purchase any prospects or engage in any oil and gas activities during 2005.

During 2006, the Partnership purchased working interests in 12 prospects, upon which the Partnership had drilled twenty wells at December 31, 2007 and had one well drilling. Drilling operations began during the third quarter of 2006. During 2006, drilling operations were completed on two exploratory wells and one developmental well. The wells were all unsuccessful and have been plugged and abandoned. The costs incurred in the drilling of these three wells, totaling $1,825,482, were expensed as property impairment cost during 2006. The Partnership drilled no successful wells during 2006 and had no oil and gas revenues for the year ended December 31, 2006. The Partnership incurred general and administrative expenses totaling $69,081, which included $5,203 in administrative costs provided by Reef, and $59,792 in legal, accounting, and printing costs related to SEC filings. Administrative costs incurred by Reef are primarily related to the number of wells administered by Reef, and, as such, these costs increased from $0 in 2005, when Reef had no oil and gas activities. The Partnership had no legal, accounting, and printing costs related to SEC filings during the period from inception (December 29, 2005) to December 31, 2005. Interest income earned is a function of the amount of unexpended partner capital available for short-term investment, and the number of days available for investment. Interest income totaled $691,667 for calendar year 2006, as compared to $1,212 for the period from inception (December 29, 2005) to December 31, 2005. The interest income of $691,667, offset by these general and administrative costs totaling $69,081 and property impairment costs totaling $1,825,482, resulted in the Partnership net loss for 2006 of $1,202,896.

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, 2007 and 2006, the Partnership was not involved in any unconsolidated SPE transactions or any other off-balance sheet arrangements.

Contractual Obligations Table

	Payment due by period
Contractual obligations	Total		Less than 1 Year		1-3 Years		3-5 years	More than 5 Years
Purchase obligations *	$	760,096	$	330,000	$	430,096	—	—

* The 15% management fee due Reef for organization and offering costs, including sales commissions, is payable in two parts. Reef initially received an amount, not to exceed 13.5%, to recover actual commissions and organization and offering costs. As of December 31, 2007, the Partnership is obligated to pay Reef $760,096 representing the portion of the management fee in excess of actual commissions and organization and offering costs, from the oil and gas cash flows available for partner distributions at a rate not to exceed $1 million per year. The Partnership began paying this balance at a rate of $30,000 per month beginning in February 2008.

ITEM 7A.

QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Interest Rate Risk

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

Commodity Price Risk

The Partnership has not and does not expect to engage in commodity futures trading or hedging activities or enter into derivative financial instrument transactions for trading or other speculative purposes. The Partnership sells a 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, 2007, a 10% change in the price received for our crude oil would have had an approximate $110,000 impact on our oil revenues, and a 10% change in the price received for our natural gas would have had an approximate $41,500 impact on our natural gas revenues.

ITEM 8.

FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

The Partnership’s financial statements and supplementary data are set forth in a separate section to this Annual Report, beginning on page F-1.

ITEM 9.

CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE

None.

ITEM 9A(T).

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 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 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 officer of our managing general partner, as appropriate to allow timely decisions regarding financial disclosure.

Management Report on Internal Control Over Financial Reporting

Management of the Partnership is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rule 13a-15(f). Our management conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on this evaluation under the framework in Internal Control – Integrated Framework, management of the Partnership concluded that the Partnership’s internal control over financial reporting was effective as of December 31, 2007.

This annual report does not include an attestation report of the Partnership’s 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 temporary 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, 2007 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	51	Manager of Reef Oil & Gas Partners GP, LLC; Chief Executive Officer of RELP
Kellam Colquitt	60	Chief Operating Officer of RELP
H. Walt Dunagin	50	Vice President—Land Manager of RELP
Lawrence J. Harrison, Jr.	57	Vice President – Business Development of RELP
Byron H. Dean	58	Manager of Acquisitions and Divestitures of RELP
Daniel C. Sibley	56	Chief Financial Officer of Reef and of RELP
David M. Tierney	55	Controller––Reef Global Energy Ventures II

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, 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.

Kellam Colquitt joined RELP as Chief Operating Officer on February 14, 2006. Mr. Colquitt has over thirty-five years of experience in the oil and gas industry. Prior to joining RELP, Mr. Colquitt served as Vice President-Exploration of Vintage Petroleum, Inc. in Tulsa Oklahoma from 2001-2006. He also served as the General Manager-Exploration of Vintage Petroleum, Inc. from 2000-2001. Prior to that, Mr. Colquitt was employed from 1995-2000, first as Vice President-International Exploration Western Hemisphere and later as Vice President-U.S. Operations for Ranger Oil Limited. He is a 1971 graduate of Texas A&M University with a degree in geology. He is a member of the American Association of Petroleum Geologists, the Houston Petroleum Club, the Tulsa Geological Society, and the Houston Geological Society.

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

Lawrence J. Harrison, Jr. is Vice President – Business Development of RELP. He joined RELP in October 2006 following fourteen years with The Oil & Gas Asset Clearinghouse, a leading acquisition and divestiture advisory firm. Mr. Harrison has served as an independent landman verifying title ownership and acquiring leases and other agreements in support of clients drilling programs. He worked for Mobil Oil Corporation and several other companies before joining The Clearinghouse. Mr. Harrison is a 1972 graduate of the University of Southern Mississippi with a Bachelor of Science degree in Communications. Mr. Harrison is a past president of the Houston Association of Professional Landmen and a past member of the American Association of Professional Landmen Executive Committee. He is currently a Director of the Louisiana Oil & Gas Association (LOGA) and a member of the ADAM Energy Forum and the Independent Petroleum Association of America.

Byron H. (Howard) Dean is Manager – Acquisitions and Divestitures of RELP and is responsible for solicitation and technical evaluation of acquisition and development opportunities for Reef. A registered petroleum engineer, Mr. Dean has over 30 years of industry experience with oil and natural gas operations and reservoir engineering, both domestic onshore and offshore. Prior to joining RELP, Mr. Dean was Senior Petroleum Engineer and Acquisition and Divestiture Specialist for PLS, Inc. and Noble Royalties, Inc. He is a 1974 graduate of the University of Texas at Arlington with a Bachelor of Science degree in Civil Engineering. Mr. Dean is an active member of the Society of Petroleum Engineers, the Society of Petroleum Evaluation Engineers, the ADAM Energy Forum, and Texas Independent Producer and Royalty Owners Association.

Daniel C. Sibley became Chief Financial Officer of Reef in December 1999. He has served in the same position for RELP since January 2006, and has served in this 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 (L.L.M.) from Southern Methodist University in 1984.

David M. Tierney has been employed by RELP since January 2006 and was previously with its predecessor entity, OREI, since March 2001. Mr. Tierney is 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 any person, 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

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

Reef is entitled to receive a management fee equal to 15% of the Partnership subscriptions exclusive of the units purchased by Reef. From this amount Reef pays all of the Partnership’s organization and offering costs, including sales commissions. The management fee is payable to Reef in two parts. Reef initially received an amount not to exceed 13.5% to cover actual sales commissions and actual organization and offering costs. The remainder of the management fee is paid to Reef from the net cash flow available for partner distributions, at a rate not to exceed $1 million per year. The total management fee owed Reef is $3,464,188. The Partnership recorded $3,414,188 of this amount as offering costs, and $50,000 as organization costs. Of this amount, $2,689,092 has been paid to Reef to cover actual sales commissions and organization and offering costs, $15,000 has been paid to Reef from net cash flow, and $760,096 has been accrued at December 31, 2007 as an account payable to be paid to Reef from future net cash flows of the Partnership.

Reef will be 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, 2007 and 2006, the Partnership reimbursed Reef $945,521 and $217,183, respectively, for technical services costs which have been capitalized as project costs, and $57,221 and $5,203, respectively, for administrative costs included as general and administrative expenses. There were no reimbursable costs incurred by Reef for the period from inception (December 29, 2005) to December 31, 2005.

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. During the year ended December 31, 2007, the Partnership paid operator fees totaling $51,700 to RELP. No fees were paid during the year ended December 31, 2006 and during the period from inception (December 29, 2005) to December 31, 2005. RELP serves as operator for four Partnership prospects upon which nine successful and two unsuccessful wells have been drilled, and for the Sand Dunes prospect, where the Partnership has participated in the drilling of eight wells. Of the eight Sand Dunes prospect wells, four wells are undergoing extended testing and evaluation in order to determine their potential commercial productivity. The Partnership estimates that it may take between 90 and 120 days from the date of this Annual Report to finish the evaluation process. Following initial testing which confirmed the presence of oil and natural gas, the remaining four Sand Dunes prospect wells were temporarily shut in due to the high cost associated with salt water disposal and generator rental.

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, 2007 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 interests 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)	48.620	5.00	%	4.45	%
Reef Oil & Gas Partners, L.P. (1)	—	—		11.00	%

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

The managing general partner received a 10% interest in the Partnership as compensation for forming the Partnership, and also holds a 1% interest in the Partnership as a result of paying 1% of all leasehold, drilling and completion costs. In addition to this 11% interest not represented by Partnership units, Reef purchased 5% of the 972.404 Partnership units and, therefore, holds 5% of the 89% interest in the Partnership (4.45%) held by the unit holders.

ITEM 13.

CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE

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

ITEM 14.

PRINCIPAL ACCOUNTING FEES AND SERVICES

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

	2007		2006
Audit fees	$	43,561	$	45,249
Audit related fees	—		—
Tax fees	866		615
All other fees	—		—

Tax fees are for review of the Partnership’s tax return.

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

Reef Global Energy VII, L.P.

Balance Sheets

December 31,	2007		2006

Assets

Current assets:
Cash and cash equivalents	$	1,261,615	$	14,571,339
Accounts receivable from affiliates	10,969		40,437
Total current assets	1,272,584		14,611,776

Oil and gas properties, full cost method of accounting:
Proved properties, net of accumulated depletion of $13,640,391 and $1,825,482	7,175,691		—
Unproved properties	172,447		3,211,249
Net oil and gas properties	7,348,138		3,211,249

Other assets:
Prepaid drilling costs	—		3,963,595
Total other assets	—		3,963,595

Total assets	$	8,620,722	$	21,786,620

Liabilities and partnership equity

Current liabilities:
Accounts payable to affiliates	598,728		1,542,848
Total current liabilities	598,728		1,542,848

Long-term liabilities:
Asset retirement obligation	125,705		—
Accounts payable to affiliates	430,096		1,028,110
Total long-term liabilities	555,801		1,028,110

Commitments and Contingencies (Note 6)

Partnership equity
General partners	5,624,838		14,591,765
Limited partners	1,387,493		3,599,369
Managing general partner	453,862		1,024,528
Partnership equity	7,466,193		19,215,662

Total liabilities and partnership equity	$	8,620,722	$	21,786,620

See accompanying notes to financial statements.

F-2

Reef Global Energy VII, L.P.

Statements of Operations

	Year ended December 31, 2007			Year ended December 31, 2006			Period from inception (December 29, 2005) to December 31, 2005

Revenues:	$	1,517,970		$	—		$	—

Costs and expenses:
Lease operating expenses	149,307			—			—
Production taxes	82,682			—			—
Depreciation, depletion and amortization	1,075,372			—			—
Property impairment	10,739,537			1,825,482			—
Accretion of asset retirement obligation	4,643			—			—
General and administrative	135,603			69,081			475
Organization expenses	—			—			50,000
Total costs and expenses	12,187,144			1,894,563			50,475

Loss from operations	(10,669,174		)	(1,894,563		)	(50,475		)

Other income:
Interest income	317,661			691,667			1,212
Total other income	317,661			691,667			1,212

Net loss	$	(10,351,513	)	$	(1,202,896	)	$	(49,263	)

Net loss per general partner unit	$	(10,689.32	)	$	(1,290.26	)	$	(729.60	)
Net loss per limited partner unit	$	(10,689.32	)	$	(1,283.33	)	$	(719.23	)
Net loss per managing general partner unit	$	(9,808.55	)	$	(251.74	)	$	(20.58	)

See accompanying notes to financial statements.

F-3

Reef Global Energy VII, L.P.

Statements of Partnership Equity

	General partners			Limited partners			Managing general partner			Total
	Units	Amount		Units	Amount		Units	Amount		Units	Amount
Partner contributions, net of offering costs	52.700	$1,158,836		14.932	$328,352		3.560	$75,641		71.192	$1,562,829
Partner distributions	—	—		—	—		—	—		—	—
Net loss	—	(38,450	)	—	(10,740	)	—	(73	)	—	(49,263	)
Balance at December 31, 2005	52.700	1,120,386		14.932	317,612		3.560	75,568		71.192	1,513,566

Distribution amount per partnership unit		—			—			—

Balance at December 31, 2005	52.700	1,120,386		14.932	317,612		3.560	75,568		71.192	1,513,566
Partner contributions, net of offering costs	688.301	14,627,534		167.851	3,565,680		45.060	1,006,778		901.212	19,199,992
Partner distributions	—	(200,071	)	—	(49,351	)	—	(45,578	)	—	(295,000	)
Net loss	—	(956,084	)	—	(234,572	)	—	(12,240	)	—	(1,202,896	)
Balance at December 31, 2006	741.001	14,591,765		182.783	3,599,369		48.620	1,024,528		972.404	19,215,662

Distribution amount per partnership unit		270.00			270.00			937.43

Balance at December 31, 2006	741.001	14,591,765		182.783	3,599,369		48.620	1,024,528		972.404	19,215,662
Partner contributions	—	—		—	—		—	144,544		—	144,544
Partner distributions	—	(1,046,134	)	—	(258,050	)	—	(238,316	)	—	(1,542,500	)
Net loss	—	(7,920,793	)	—	(1,953,826	)	—	(476,894	)	—	(10,351,513	)
Balance at December 31, 2007	741.001	$5,624,838		182.783	$1,387,493		48.620	$453,862		972.404	$7,466,193

Distribution amount per partnership unit		$1,411.78			$1,411.78			$4,901.60

See accompanying notes to financial statements.

F-4

Reef Global Energy VII, L.P.

Statements of Cash Flows

							Period from inception (December 29, 2005) to
	Year Ended						December 31,
	2007			2006			2005
Operating Activities
Net loss	$	(10,351,513	)	$	(1,202,896	)	$	(49,263	)
Adjustments for non-cash transactions:
Depreciation, depletion and amortization	1,075,372						—
Property impairment	10,739,537			1,825,482			—
Accretion of asset retirement obligation	4,643						—
Adjustments to reconcile net loss to net cash provided by operating activities:
Changes in operating assets and liabilities:
Accounts receivable	—			1,177			(1,177		)
Accounts payable	—			(475		)	475
Accounts payable to affiliates	21,118			(80,263		)	80,263
Net cash provided by operating activities	1,489,157			543,025			30,298

Investing Activities
Property acquisition and development	(13,162,379		)	(3,493,883		)	—
Prepaid drilling costs	—			(3,963,595		)	—
Net cash used in investing activities	(13,162,379		)	(7,457,478		)	—

Financing Activities
Partner capital contributions	174,012			22,445,763			1,690,809
Offering costs	(268,014		)	(2,182,457		)	(203,621		)
Partner distributions	(1,542,500		)	(295,000		)	—
Net cash provided by (used in) financing activities	(1,636,502		)	19,968,306			1,487,188

Net increase (decrease) in cash and cash equivalents	(13,309,724		)	13,053,853			1,517,486
Cash and cash equivalents at beginning of period	14,571,339			1,517,486			—
Cash and cash equivalents at end of period	$	1,261,615		$	14,571,339		$	1,517,486

Non-cash investing transactions
Property additions included in accounts payable to affiliates	$	247,610		$	1,542,848		$	—
Property additions and asset retirement obligation	$	121,062		$	—		$	—
Non-cash financing transactions:
Managing partner contributions included in accounts receivable from affiliates	$	10,969		$	40,437		$	75,641
Offering costs included in accounts payable to affiliates	$	330,000		$	—		$	—
Offering costs included in non-current accounts payable to affiliates	$	430,096		$	1,028,110		$	—

See accompanying notes to financial statements.

F-5

Reef Global Energy VII, L.P.

Notes to Financial Statements (continued)

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 accounts for its asset retirement obligations in accordance with Statement of Financial Accounting Standards (“SFAS”) No. 143, “Accounting for Asset Retirement Obligations” (“SFAS No. 143”). Asset retirement costs and liabilities associated with future site restoration and abandonment of long-lived assets are initially measured at fair value which approximates the cost a third party would incur in performing the tasks necessary to retire such assets. The fair value is recognized in the financial statements as the present value of expected future cash expenditures for site restoration and abandonment. Subsequent to the initial measurement, the effect of the passage of time on the liability for the net asset retirement obligation (accretion expense) and the amortization of the asset retirement cost are recognized in the results of operations.

The following table summarizes the Partnership’s asset retirement obligation for the year ended December 31, 2007.

	2007
Beginning asset retirement obligation	$	—
Additions related to new properties	121,062
Accretion expense	4,643
Ending asset retirement obligation	$	125,705

Recognition of Revenue

The Partnership enters into sales contracts for disposition of its share of 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, 2007, 2006, and 2005.

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, 2007, the tax basis of the Partnership’s assets exceeds the financial reporting basis of the assets by approximately $125,000, primarily due to the difference between property impairment costs deducted for financial reporting purposes and intangible drilling costs deducted for income tax purposes.

F-9

Reef Global Energy VII, L.P.

Notes to Financial Statements (continued)

Of the eight Sand Dunes prospect wells, four wells are undergoing extended testing and evaluation in order to determine their potential commercial productivity. The Partnership estimates that it may take between 90 and 120 days from the date of this report to finish the evaluation process. Following initial testing which confirmed the presence of oil and natural gas, the remaining four Sand Dunes prospect wells were temporarily shut in due to the high cost associated with salt water disposal and generator rental.

Currently, generators have been rented to power the four producing Sand Dunes prospect wells undergoing the evaluation process, and salt water produced is being trucked off-site by an independent vendor. In order to reduce overall costs, installation of electric service to the well-site locations is proceeding, and a more cost effective method of salt water disposal is being explored. To date, RELP, the operator of these wells, has been unsuccessful in locating a long-term economic solution for disposing of produced salt water; however, RELP is currently evaluating its options for salt water disposal, and estimates that it will be at least 90 to 120 days from the date of this report for the Sand Dunes prospect to have electricity and efficient salt water disposal capability in place.

In addition to the three Sand Dunes prospect wells drilling at December 31, 2007, a fourth well on a different prospect was drilling at December 31, 2007. The well finished drilling operations during February 2008, is currently being completed, and is expected to begin production during the second quarter of 2008.

10. 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,	2007			2006

Oil and natural gas properties:
Unproved properties	$	172,447		$	3,211,249
Proved properties	20,816,082			1,825,482
	20,988,529			5,036,731
Less:
Accumulated depreciation, depletion and amortization	(1,075,372		)	—
Property impairment	(12,565,019		)	(1,825,482		)
Total	$	7,348,138		$	3,211,249

F-14

Reef Global Energy VII, L.P.

Notes to Financial Statements (continued)

Costs Incurred

The following table sets forth costs incurred in oil and gas exploration and development activities during the years ended December 31, 2007 and 2006:

	2007		2006

Oil and natural gas properties:
Exploration	$	3,691,736	$	3,482,548
Development	12,260,062		1,554,183
Total	$	15,951,798	$	5,036,731

Results of Operations

The following table sets forth results of operations from oil and gas producing activities for the years ended December 31, 2007 and 2006.

	2007			2006

Oil and gas producing activities:
Oil sales	$	1,102,915		$	—
Natural gas sales	415,055			—
Production expenses	(231,989		)	—
Accretion of asset retirement obligation	(4,643		)	—
Depreciation , depletion and amortization	(1,075,372		)	1,825,482
Property impairment expense	(10,739,537		)	—
Results of operations from producing activities	$	(10,533,571	)	$	1,825,482

Depletion rate per BOE	$	48.70		$	—

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

Oil and Natural Gas Reserves

The following information describes changes during the year and balances of proved oil and natural gas reserves as of December 31, 2007. The Partnership had no proved oil and natural gas reserves at December 31, 2006 and 2005. The definitions used are in accordance with applicable Securities and Exchange Commission regulations.

Proved oil and natural gas reserves are the estimated quantities of crude oil, natural gas and natural gas liquids which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions, that is, prices and costs as of the date the estimate is made.

F-15

Reef Global Energy VII, L.P.

Notes to Financial Statements (continued)

Prices include consideration of changes in existing prices provided by contractual arrangements, but not escalations based upon future conditions. Additional development costs required to recover these proved reserves are estimated at approximately $274,087 as of December 31, 2007. All of the Partnership’s reserves are located in the United States.

	Oil (BBL) (1)		Gas (mcf)		BOE (2)
Net proved reserves for properties owned by the Partnership
Reserves at December 31, 2006	—		—		—
New discoveries	110,903		804,018		244,906
Production	(14,032	)	(48,301	)	(22,082	)
Reserves at December 31, 2007	96,871		755,717		222,824

(1) Oil includes both oil and natural gas liquids

(2) BOE (barrels of oil equivalent) is calculated by converting 6 MCF of natural gas to 1 BBL of oil. A BBL (barrel) of 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

As required by the Financial Accounting Standards Board, the standardized measure of discounted future net cash flows is computed by applying year-end prices, costs and legislated tax rates and a discount factor of 10 percent to net proved reserves.

Changes in the demand for oil and natural gas, inflation, and other factors make such estimates inherently imprecise and subject to substantial revision. This table should not be construed to be an estimate of the current market value of the Partnership’s proved reserves.

December 31,	2007
Oil and natural gas properties owned by the Partnership:
Future cash inflows	$	13,857,388
Future production costs	(4,277,881		)
Future development costs	(274,087		)
Future net cash flows	$	9,305,420
Effect of discounting net cash flows at 10%	(2,106,058		)
Discounted future net cash flows	$	7,199,362

F-16

Reef Global Energy VII, L.P.

Notes to Financial Statements (continued)

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

December 31,	2007
Oil and natural gas properties owned by the Partnership:
Standardized measure at beginning of period	$	—
Extensions and discoveries	8,480,700
Sales net of production costs	(1,281,338		)
Net increase	7,199,362
Standardized measure at end of year	$	7,199,362

11. Supplementary Quarterly Financial Data (Unaudited)

Period from Inception (December 29, 2005) to December 31, 2005	4th Qtr			Totals
Total oil and natural gas sales	$	—		$	—
Loss from operations	(50,475		)	(50,475		)
Net loss	(49,263		)	(49,263		)
Net loss per managing general partner unit	(20.58		)	(20.58		)
Net loss per general partner unit	(729.60		)	(729.60		)
Net loss per limited partner unit	(719.23		)	(719.23		)

Net loss allocated to partners other than the managing general partner differs due to the allocation of interest income among the partners.

Year ended December 31, 2006	1st Qtr			2nd Qtr			3rd Qtr			4th Qtr			Totals
Total oil and natural gas sales	$	—		$	—		$	—		$	—		$	—
Loss from operations	(19,153		)	(37,339		)	(545,482		)	(1,292,589		)	(1,894,563		)
Net income (loss)	17,602			148,668			(319,810		)	(1,049,356		)	(1,202,896		)
Net income (loss) per managing general partner unit	(55.05		)	587.25			11.04			(794.98		)	(251.74		)
Net income (loss) per general partner unit	19.99			130.62			(346.78		)	(1,094.09		)	(1,290.26		)
Net income (loss) per limited partner unit	29.92			127.62			(346.78		)	(1,094.09		)	(1,283.33		)

Property impairment expense included in the above amounts is as follows:

1^st quarter — $0, 2^nd quarter — $0, 3^rd quarter — $525,746, 4^th quarter — $1,299,736

F-17

Reef Global Energy VII, L.P.

Notes to Financial Statements (continued)

Net loss allocated to partners other than the managing general partner differs due to the allocation of interest income among the partners.

Year ended December 31, 2007	1st Qtr			2nd Qtr			3rd Qtr		4th Qtr			Totals
Total oil and natural gas sales	$	9,579		$	147,135		$	635,516	$	725,740		$	1,517,970
Income (loss) from operations	(3,967,639		)	(551,505		)	221,902		(6,371,932		)	(10,669,174		)
Net income (loss)	(3,824,681		)	(451,722		)	274,075		(6,349,185		)	(10,351,513		)
Net income (loss) per managing general partner unit	(4,411.83		)	(228.53		)	1,458.46		(6,626.65		)	(9,808.55		)
Net income (loss) per general partner unit	(3,908.03		)	(476.97		)	219.93		(6,524.25		)	(10,689.32		)
Net income (loss) per limited partner unit	(3,908.03		)	(476.97		)	219.93		(6,524.25		)	(10,689.32		)

Property impairment expense included in the above amounts is as follows:

1^st quarter — $3,884,152, 2^nd quarter — $540,144, 3^rd quarter — $0, 4^th quarter — $6,315,241

F-18

Part I

Item 1.		Business
Item 1A.		Risk Factors
Item 1B.		Unresolved Staff Comments
Item 2.		Properties
Item 3.		Legal Proceedings
Item 4.		Submission of matters to a Vote of Security Holders

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 Disclosures 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(T).		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 Accounting Fees and Services

PART IV

Item 15.		Exhibits and Financial Statement Schedules
		Signatures

Signature	Title	Date

/s/ Michael J. Mauceli	Manager and Member of the general partner of Reef Oil & Gas	April 15, 2008
Michael J. Mauceli	Partners, L.P. (Principal Executive Officer)

/s/ Daniel C. Sibley	Chief Financial Officer (Principal Financial Officer and Principal	April 15, 2008
Daniel C. Sibley	Accounting Officer)

3.1		Certificate of Limited Partnership (incorporated by reference to Exhibit 3.1 to Form 8-A, SEC File No. 000-52540, as filed with the SEC on March 30, 2007).

3.2		Form of Limited Partnership Agreement (incorporated by reference to Appendix A to the prospectus filed as part of Post-Effective Amendment No. 2 to Registration Statement on Form S-1, SEC File No.333-122935, filed with the SEC on July 7, 2006).

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 Report on Form 10-K of Reef Global Energy Ventures as filed with the SEC on March 5, 2002).

23.2	*	Consent of Gleason Engineering.

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.

COMMISSION FILE NUMBER 333-122935-02

Documents incorporated by reference: None

Manager (Principal Executive Officer)

Oil and Natural Gas Properties

Restoration, Removal, and Environmental Liabilities

(a)	1. Financial Statements

	Report of Independent Registered Public Accounting Firm	F-1
	Balance Sheets	F-2
	Statements of Operations	F-3
	Statements of Partnership Equity	F-4
	Statements of Cash Flows	F-5
	Notes to Financial Statements	F-6


	2. Financial Statement Schedules	None

	3. Exhibits

Date: April 15, 2008	REEF GLOBAL ENERGY VII, L.P.


	Reef Oil & Gas Partners, L.P.
	Managing General Partner

	By:	Reef Oil & Gas Partners, GP, LLC

	By:	/s/ Michael J. Mauceli
		Michael J. Mauceli
		Manager (Principal Executive 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	F-4
Statements of Cash Flows	F-5
Notes to Financial Statements	F-6