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**UNITED STATES**

**SECURITIES AND EXCHANGE COMMISSION**

**Washington, D.C. 20549**

 

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**FORM 10-Q**

 

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

** **

**For the Quarterly Period Ended March 31,2009**

** **

**OR**

** **

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

** **

**For the Transition Period from                to                **

** **

**Commission File Number: 333-122935-01**

** **

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

(Exact name of registrant as specified in its charter)

 

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

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

identification  no.) |

 

| **1901 N.  Central Expressway, Suite 300**

**Richardson,  Texas 75080** | ** ** | **75080-3609** |
|-------------------------------------------------------------------------------|------------|----------------|
| (Address of  principal executive offices)                                     | ** ** | (Zip code)     |

 

Registrant’stelephone number, including area code: **(972)-437-6792**

 

Indicateby check mark whether the registrant (1) has filed all reports required tobe filed by Section 13 or 15(d) of the Securities Exchange Act of1934 during the preceding 12 months (or for such shorter period that theregistrant was required to file such reports), and (2) has been subject tosuch filing requirements for the past 90 days. Yes  x     No  o

 

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

 

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

 

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

 

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

 

**As of March 31, 2009, theregistrant had 75.363 units of general partner interest held by the managinggeneral partner, and 1,431.897 units of limited partner interest outstanding.**

 

 

 

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**ReefGlobal Energy VI, L.P.**

**Form 10-Q Index**

 
| **PART I —  FINANCIAL INFORMATION** |                                                                                            |
|-----------------------------------------------|-------------------------------------------------------------------------------------------------|
|                                          |                                                                                            |
| **ITEM  1.**                                  | **Financial Statements (Unaudited)**                                                            | ** ** |
|                                          | *Condensed  Balance Sheets*                                                                     |   |
|                                          | *Condensed  Statements of Operations*                                                           |   |
|                                          | *Condensed  Statements of Cash Flows*                                                           |   |
|                                          | *Notes  to Condensed Financial Statements*                                                      |   |
|                                          |                                                                                            |   |
| **ITEM 2.**                                   | **Management’s  Discussion and Analysis of Financial Condition and Results of Operations** | ** ** |
|                                          |                                                                                            |   |
| **ITEM 3.**                                   | **Quantitative  and Qualitative Disclosures About Market Risk**                                 | ** ** |
|                                          |                                                                                            |   |
| **ITEM 4T.**                                  | **Controls and  Procedures**                                                                    | ** ** |
|                                          |                                                                                            |   |
| **PART II  — OTHER INFORMATION**    | ** **                                                                                      |
|                                          |                                                                                            |   |
| **ITEM 1.**                                   | **Legal Proceedings**                                                                           | ** ** |
|                                          |                                                                                            |   |
| **ITEM 2.**                                   | **Unregistered  Sales of Equity Securities and Use of Proceeds**                                | ** ** |
|                                          |                                                                                            |   |
| **ITEM 3.**                                   | **Default Upon  Senior Securities**                                                             | ** ** |
|                                          |                                                                                            |   |
| **ITEM 4.**                                   | **Submission of  Matters to a Vote of Security Holders**                                        | ** ** |
|                                          |                                                                                            |   |
| **ITEM 5.**                                   | **Other Information**                                                                           | ** ** |
|                                          |                                                                                            |   |
| **ITEM  6.**                                  | **Exhibits**                                                                                    | ** ** |
|                                          |                                                                                            |
| **Signatures**                                |                                                                                            |

 

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# **PART I FINANCIAL INFORMATION**

# ** **

## **Item 1. Financial Statements**

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

**Condensed Balance Sheets**

 
| ** **                                                                      | ** ** | **March 31,  2008** | ** **    | **December 31,  2008** | ** ** |
|---------------------------------------------------------------------------------|------------|--------------------------|---------------|-----------------------------|------------|
| ** **                                                                      | ** ** | **(unaudited)**          | ** **    | ** **                  | ** ** |
| **Assets**                                                                      |       |                     |          |                        |       |
| ** **                                                                      |       |                     |          |                        |       |
| **Current  assets:**                                                            |       |                     |          |                        |       |
| Cash and cash  equivalents                                                      | ** ** | **$**                    | 197,530       |                        | **$**      | 1,125,458 | ** ** |
| Accounts  receivable                                                            |       | 2,680                    |          | 2,680                       |       |
| Accounts  receivable from affiliates                                            |       | 695,961                  |          | 144,486                     |       |
| Prepaid expenses                                                                |       | 5,011                    |          | —                      |       |
| **Total  current assets**                                                       | ** ** | **901,182**              | ** **    | **1,272,624**               | ** ** |
|                                                                            |       |                     |          |                        |       |
| **Oil and  gas properties, full cost method of accounting:**                    |       |                     |          |                        |       |
| Proved  properties, net of accumulated depletion of $26,180,621 and $22,961,256 |       | 7,253,365                |          | 10,266,854                  |       |
| **Net oil  and gas properties**                                                 | ** ** | **7,253,365**            | ** **    | **10,266,854**              | ** ** |
| ** **                                                                      | ** ** | ** **               | ** **    | ** **                  | ** ** |
| **Total  Assets**                                                               | ** ** | **$**                    | **8,154,547** | ** **                  | **$**      | **11,539,478** | ** ** |
|                                                                            |       |                     |          |                        |       |
| **Liabilities  and partnership Equity**                                         |       |                     |          |                        |       |
|                                                                            |       |                     |          |                        |       |
| **Current  liabilities:**                                                       |       |                     |          |                        |       |
| Accounts payable                                                                | ** ** | **$**                    | 9,723         |                        | **$**      | 5,161 | ** ** |
| Accounts payable  to affiliates                                                 |       | —                   |          | 144,789                     |       |
| **Total  current liabilities**                                                  | ** ** | **9,723**                | ** **    | **149,950**                 | ** ** |
|                                                                            |       |                     |          |                        |       |
| **Long-term  liabilities:**                                                     |       |                     |          |                        |       |
| Asset retirement  obligation                                                    |       | 391,276                  |          | 386,346                     |       |
| **Total  long-term liabilities**                                                | ** ** | **391,276**              | ** **    | **386,346**                 | ** ** |
| ** **                                                                      | ** ** | ** **               | ** **    | ** **                  | ** ** |
| **Partnership  equity**                                                         |       |                     |          |                        |       |
| General partners                                                                |       | —                   |          | —                      |       |
| Limited partners                                                                |       | 7,183,465                |          | 10,235,797                  |       |
| Managing general  partner                                                       |       | 570,083                  |          | 767,385                     |       |
| **Partnership  equity**                                                         | ** ** | **7,753,548**            | ** **    | **11,003,182**              | ** ** |
| ** **                                                                      | ** ** | ** **               | ** **    | ** **                  | ** ** |
| **Total  liabilities and partnership equity**                                   | ** ** | **$**                    | **8,154,547** | ** **                  | **$**      | **11,539,478** | ** ** |

 

*See accompanying notes tocondensed financial statements.*

 

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

**Condensed Statements ofOperations**

**(Unaudited)**

*** ***
| ** **                                  | ** ** | **For the three months ended  March 31** | ** **     |
|---------------------------------------------|------------|-----------------------------------------------|----------------|
| ** **                                  | ** ** | **2009**                                      | ** **     | **2008** | ** ** |
|                                        |       |                                          |           |   |   |
| **Revenues**                                | ** ** | **$**                                         | **1,234,083**  | ** ** | **$** | **1,920,280** | ** ** |
|                                        |       |                                          |           |   |   |
| **Costs  and expenses:**                    |       |                                          |           |   |   |
| Lease operating  expenses                   |       | 246,789                                       |           | 206,421 |   |
| Production taxes                            |       | 90,080                                        |           | 135,203 |   |
| Depreciation,  depletion and amortization   |       | 802,032                                       |           | 494,688 |   |
| Property  impairment                        |       | 2,417,333                                     |           | — |   |
| Accretion of  asset retirement obligation   |       | 7,562                                         |           | 4,060 |   |
| General and  administrative                 |       | 154,233                                       |           | 115,824 |   |
| **Total  costs and expenses**               | ** ** | **3,718,029**                                 | ** **     | **956,196** | ** ** |
|                                        |       |                                          |           |   |   |
| **Income  (loss) from operations**          | ** ** | **(2,483,946**                                | **)**          | **964,084** | ** ** |
|                                        |       |                                          |           |   |   |
| **Other  income:**                          |       |                                          |           |   |   |
| Interest income                             |       | 2,058                                         |           | 10,574 |   |
| **Total  other income**                     | ** ** | **2,058**                                     | ** **     | **10,574** | ** ** |
|                                        |       |                                          |           |   |   |
| **Net  income (loss)**                      | ** ** | **$**                                         | **(2,481,888** | **)** | **$** | **974,658** | ** ** |
|                                        |       |                                          |           |   |   |
| Net income  (loss) per general partner unit | ** ** | **$**                                         | **(1,044.08**  | **)** | **$** | **543.31** | ** ** |
| Net income  (loss) per limited partner unit | ** ** | **$**                                         | **(1,678.34**  | **)** | **$** | **543.31** | ** ** |
| Net loss per  managing general partner unit | ** ** | **$**                                         | **—**     | ** ** | **$** | **2,609.96** | ** ** |

 

*Seeaccompanying notes to condensed financial statements.*

 

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

**Condensed Statements of CashFlows**

**(Unaudited)**

 
| ** **                                                                                | ** ** | **For the three months ended  March 31** | ** **  |
|-------------------------------------------------------------------------------------------|------------|-----------------------------------------------|-------------|
| ** **                                                                                | ** ** | **2009**                                      | ** **  | **2008** | ** ** |
| ** **                                                                                | ** ** | ** **                                    | ** **  | ** ** | ** ** |
| **Operating  Activities**                                                                 |       |                                          |        |   |   |
| Net income  (loss)                                                                        | ** ** | **$**                                         | (2,481,888  | **)** | **$** | 974,658 | ** ** |
| Adjustments for  non-cash transactions:                                                   |       |                                          |        |   |   |
| Depreciation,  depletion and amortization                                                 |       | 802,032                                       |        | 494,688 |   |
| Property  impairment                                                                      |       | 2,417,333                                     |        | — |   |
| Accretion of  asset retirement obligation                                                 |       | 7,562                                         |        | 4,060 |   |
| Adjustments to  reconcile net income (loss) to net cash provided by operating activities: |       |                                          |        |   |   |
| Changes in  operating assets and liabilities:                                             |       |                                          |        |   |   |
| Accounts  receivable from affiliates                                                      |       | (551,475                                      | )           | (1,117,683 | ) |
| Prepaid expenses                                                                          |       | (5,011                                        | )           | — |   |
| Accounts payable                                                                          |       | 4,562                                         |        | (1,708 | ) |
| Accounts payable  to affiliates                                                           |       | (144,789                                      | )           | 105,677 |   |
| **Net  cash provided by operating activities**                                            | ** ** | **48,326**                                    | ** **  | **459,692** | ** ** |
| ** **                                                                                | ** ** | ** **                                    | ** **  | ** ** | ** ** |
| **Investing  Activities**                                                                 | ** ** | ** **                                    | ** **  | ** ** | ** ** |
| Property  acquisition and development                                                     |       | (205,875                                      | )           | (542,591 | ) |
| Plugging and  abandonment costs paid from asset retirement obligation                     |       | (2,632                                        | )           | — |   |
| **Net  cash used in investing activities**                                                | ** ** | **(208,508**                                  | **)**       | **(542,591** | **)** |
| ** **                                                                                | ** ** | ** **                                    | ** **  | ** ** | ** ** |
| **Financing  Activities**                                                                 | ** ** | ** **                                    | ** **  | ** ** | ** ** |
| Partner capital  contributions                                                            |       | —                                        |        | 15,098 |   |
| Offering costs                                                                            |       | (144,789                                      | )           | (100,000 | ) |
| Partner  distributions                                                                    |       | (622,957                                      | )           | (1,323,000 | ) |
| **Net  cash used in financing activities**                                                | ** ** | **(767,746**                                  | **)**       | **(1,407,902** | **)** |
| ** **                                                                                | ** ** | ** **                                    | ** **  | ** ** | ** ** |
| **Net  decrease in cash and cash equivalents**                                            | ** ** | **(927,928**                                  | **)**       | **(1,490,801** | **)** |
| Cash and cash  equivalents at beginning of period                                         |       | 1,125,458                                     |        | 2,366,065 |   |
| **Cash  and cash equivalents at end of period**                                           | ** ** | **$**                                         | **197,530** | ** ** | **$** | **875,264** | ** ** |
| ** **                                                                                | ** ** | ** **                                    | ** **  | ** ** | ** ** |
| **Supplemental  disclosure of non-cash investing transactions**                           | ** ** | ** **                                    | ** **  | ** ** | ** ** |
| Property  additions included in accounts payable to affiliates                            | ** ** | **$**                                         | —      |   | **$** | 16,463 | ** ** |
| Property  additions and asset retirement obligation                                       | ** ** | **$**                                         | —      |   | **$** | 17,586 | ** ** |
| **Supplemental  disclosure of non-cash financing transactions**                           | ** ** |                                          |        | ** ** | ** ** |
| Managing partner  contributions included in accounts receivable from affiliates           | ** ** | **$**                                         | —      |   | **$** | — | ** ** |
| Offering costs  included in accounts payable to affiliates                                | ** ** | **$**                                         | —      |   | **$** | 600,000 | ** ** |
| Offering costs  included in long-term accounts payable to affiliates                      | ** ** | **$**                                         | —      |   | **$** | 44,789 | ** ** |

 

*See accompanying notes tocondensed financial statements.*

 

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**ReefGlobal Energy VI, L.P.**

**Notes to Condensed Financial Statements(unaudited)**

 

**1.Organization and Basis of Presentation**

 

The financial statementsof Reef Global Energy VI, L.P. (the “Partnership”) have been prepared pursuantto the rules and regulations of the Securities and Exchange Commission(the “SEC”). Certain information and footnote disclosure normally included inannual financial statements prepared in accordance with accounting principlesgenerally accepted in the United States have been condensed or omitted pursuantto those rules and regulations. We have recorded all transactions andadjustments necessary to fairly present the financial statements included inthis Quarterly Report on Form 10-Q (this “Quarterly Report”). Theadjustments are normal and recurring. The following notes describe only thematerial changes in accounting policies, account details, or financialstatement notes during the first three months of 2009. Therefore, please readthese condensed financial statements and notes to condensed financialstatements together with the audited financial statements and notes tofinancial statements contained in the Partnership’s Annual Report on Form 10-Kfor the period ended December 31, 2008 (the “Annual Report”).

 

**2.Summary of Accounting Policies**

 

**Oil andNatural Gas Properties**

 

The Partnership followsthe full cost method of accounting for crude oil and natural gas properties.Under this method, all direct costs and certain indirect costs associated withacquisition of properties and successful as well as unsuccessful explorationand development activities are capitalized. Depreciation, depletion, andamortization of capitalized crude oil and natural gas properties and estimatedfuture development costs, excluding unproved properties, are based on theunit-of-production method using estimated proved reserves. For these purposes,proved natural gas reserves are converted to equivalent barrels of crude oil ata rate of 6 MCF to 1 Bbl. Net capitalized costs of crude oil and natural gasproperties, as adjusted for asset retirement obligations, are limited to thelower of unamortized cost or the cost ceiling, defined as the sum of thepresent value of estimated future net revenues from proved reserves based onprices in effect at the end of the period held constant and discounted at 10percent, plus the lower of cost or fair value of unproved properties, if any.Pursuant to full cost accounting rules, the Partnership performs a ceiling testquarterly as of the balance sheet date on its proved crude oil and natural gasproperties. Excess capitalized costs are charged to property impairmentexpense. No gain or loss is recognized upon sale or disposition of crude oiland natural gas properties, unless such a sale would significantly alter therate of depletion and amortization. During the three month period ended March 31,2009, the Partnership recognized a property impairment expense of $2,417,333.

 

Unprovedproperties consist of undeveloped leasehold interest. Investments in unprovedproperties are not depleted pending determination of the existence of provedreserves. Unproved properties are assessed for impairment quarterly as of thebalance sheet date by considering the primary lease term, the holding period ofthe properties, geologic data obtained relating to the properties, and otherdrilling activity in the immediate area of the properties. Any impairmentresulting from this quarterly assessment is reported as property impairmentexpense in the current period, as appropriate. During the three month periodended March 31, 2009, the Partnership recognized no impairment of unprovedproperties.

 

# **Asset Retirement Obligation**

# ** **

The Partnership accountsfor its asset retirement obligations in accordance with Statement of FinancialAccounting Standards (“SFAS”) No. 143, “Accounting for Asset RetirementObligations” (“SFAS No. 143”). Asset retirement costs and liabilitiesassociated with future site restoration and abandonment of long-lived assetsare initially measured at fair value which approximates the cost a third partywould incur in performing the tasks necessary to retire such assets. The fairvalue is recognized in the financial statements as the present value ofexpected future cash expenditures for site restoration and abandonment.Subsequent to the initial measurement, the effect of the passage of time on theliability for the net asset retirement obligation (accretion expense) and theamortization of the asset retirement cost are recognized in the results ofoperations.  No gain or loss isrecognized upon abandonment and restoration of crude oil and natural gasproperties, unless such abandonment and restoration would significantly alterthe rate of depletion and amortization.

 

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The following tablesummarizes the Partnership’s asset retirement obligation for the three monthsended March 31, 2009 and the year ended December 31, 2008.

 
| ** **                                                  | ** ** | **Three months ended  March 31, 2009** | ** ** | **Year Ended  December 31, 2008** | ** ** |
|-------------------------------------------------------------|------------|---------------------------------------------|------------|----------------------------------------|------------|
| Beginning asset  retirement obligation                      | ** ** | $                                           | 386,346    |                                   | $          | 305,215 | ** ** |
| Additions  related to new properties                        |       | —                                      |       | 35,166                                 |       |
| Accretion  expense                                          |       | 7,562                                       |       | 60,786                                 |       |
| Retirement  related to property abandonment and restoration |       | (2,632                                      | )          | (14,821                                | )          |
| Ending asset  retirement obligation                         | ** ** | $                                           | 391,276    |                                   | $          | 386,346 | ** ** |

 

**New Accounting Pronouncements**

 

**Interim Reporting of Fair Value of FinancialInstruments**

 

In April 2009, the Financial Accounting StandardsBoard (the “FASB”) issued FASB Staff Position FSP FAS 107-1 and AccountingPrinciples Board (“APB”) Opinion No. 28-1 (“FSP FAS 107-1”), “InterimDisclosures about Fair Value of Financial Instruments.”  FSP FAS 107-1 amends SFAS No. 107, “Disclosuresabout Fair Value of Financial Instruments,” to require disclosures about fairvalue of financial instruments for interim reporting periods.  The FSP FAS 107-1 also amends APB Opinion No. 28,“Interim Financial Reporting,” to require those disclosures about the fairvalue of financial instruments in summarized financial information at interimreporting periods.  FSP FAS 107-1 iseffective for reporting periods ending after June 15, 2009, and itsadoption is expected to have no impact on the Partnership’s results ofoperations and financial condition but will require additional disclosuresregarding the fair value of certain financial instruments of the Partnership.

 

**Fair Value Measurements**

 

On January 1, 2009, the Partnership adopted FASBStaff Position FSP FAS No. 157-2 (“FSP FAS No. 157-2”), which delayedthe effective date of SFAS No. 157, “Fair Value Measurements” fornonfinancial assets and liabilities, except for items that are recognized ordisclosed at fair value in the financial statements on a recurring basis atleast annually.  The adoption of FSP FAS No. 157-2was immaterial to the Partnership’s results of operations, cash flows andfinancial positions.

 

**Modernization of Oil and Gas Reporting**

 

In January 2009, the SEC issued revisions to theoil and gas reporting disclosures, “Modernization of Oil and Gas Reporting;Final Rule” (“the Final Rule”). In addition to changing the definition anddisclosure requirements for oil and gas reserves, the Final Rule changesthe requirements for determining quantities of oil and gas reserves. The Final Rule alsochanges certain accounting requirements under the full cost method ofaccounting for oil and gas activities. The amendments are designed to modernizethe requirements for the determination of oil and gas reserves, aligning themwith current practices and updating them for changes in technology. The Final Rule iseffective for annual reports on Form 10-K for fiscal years ending on orafter December 31, 2009. The Partnership has not yet determined theimpact, if any, of the Final Rule on the financial statements.

 

**The Hierarchy of Generally Accepted AccountingPrinciples**

 

In May 2008, the FASB issued SFAS No. 162, “TheHierarchy of Generally Accepted Accounting Principles” (“SFAS 162”). SFAS 162identifies the sources for accounting principles and the framework forselecting the principles to be used in preparing financial statements ofnongovernmental entities that are presented in conformity with generallyaccepted accounting principles in the United States. This statement becameeffective in November 2008.

 

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**Disclosures About Derivative Instruments andHedging Activities**

 

In March 2008, the FASB issued SFAS No. 161,“Disclosures about Derivative Instruments and Hedging Activities” (“SFAS 161”).SFAS 161 requires entities that utilize derivative instruments to providequalitative disclosures about their objectives and strategies for using suchinstruments, as well as any details of credit-risk-related contingent featurescontained within derivatives. The Partnership does not utilize derivativeinstruments; therefore, this pronouncement did not have any impact on thePartnership’s results of operations, cash flows or financial position.

 

**Non-controlling Interests in ConsolidatedFinancial Statements**

 

In December 2007, the FASB issued SFAS No. 160,“Noncontrolling Interests in Consolidated Financial Statements, an amendment ofAccounting Research Bulletin No. 51” (“SFAS 160”), which improves therelevance, comparability and transparency of the financial information that areporting entity provides in its consolidated financial statements byestablishing accounting and reporting standards for the noncontrolling interestin a subsidiary and for the deconsolidation of a subsidiary. The Partnershipdoes not own any subsidiaries, and this pronouncement did not have any impacton the Partnership’s results of operations, cash flows or financial position.

 

**Business Combinations**

 

In December 2007, the FASB issued SFAS No. 141(revised 2007), “Business Combinations” (“SFAS 141R”), which replaces SFAS No. 141,“Business Combinations” (“SFAS 141”). SFAS 141R retains the fundamentalrequirements in SFAS 141 that the acquisition method of accounting (which SFAS141 called the purchase method) be used for all business combinations. ThePartnership has no business combinations in progress or, at this time, infuture plans. This pronouncement did not have any impact on the Partnership’sresults of operations, cash flows or financial position.

 

**Accounting Standard Fair Value for FinancialAssets and Financial Liabilities**

 

In February 2007, the FASB issued SFAS No. 159,“The Fair Value Option for Financial Assets and Financial Liabilities” (“SFAS159”). SFAS 159 allows entities the option to measure eligible financialinstruments at fair value as of specified dates. The Partnership did not electfair value as an alternative as provided under SFAS 159 for any of itsfinancial assets and liabilities that are not currently measured at fair value.

 

**3. Transactionswith Affiliates**

 

The Partnership has noemployees. Reef Exploration, L.P. (“RELP”), an affiliate of Reef Oil &Gas Partners, L.P. (“Reef”), the managing general partner of the Partnership,employs a staff including geologists, petroleum engineers, landmen andaccounting personnel who administer all of the Partnership’s operations. ThePartnership reimburses RELP for technical and administrative services at cost.During the three month periods ended March 31, 2009 and 2008, thePartnership incurred technical services and administrative costs totaling$137,862 and $122,140, respectively. Of these amounts, $0 and $16,463 representtechnical services costs capitalized as project costs, and $137,862 and$105,677 represent administrative costs included as general and administrativeexpenses.

 

Reef contributes 1% ofall leasehold, drilling and completion costs when incurred. In addition, Reefpurchased 5% of the Partnership units and pays 5% of the 99% of these costspaid by the unit holders (4.95%). As of March 31, 2009, this 1% obligationtotaled $0.  At December 31, 2008,Reef owed the Partnership $12,019 in connection with this obligation. ThePartnership settles its balances with Reef and RELP on a quarterly basis.

 

RELP processes jointinterest billings and revenues on behalf of the Partnership. At March 31,2009, RELP owed the Partnership $695,961 for net revenues processed in excessof joint interest and technical and administrative services charges. At December 31,2008, RELP owed the Partnership $144,486 for joint interest charges (primarilyfor drilling of wells) and technical and administrative services chargesprocessed in excess of net revenues. The cash associated with net revenuesprocessed by RELP is normally received by RELP from oil and gas purchasers30-60 days after the end of the month to which the revenues pertain.

 

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Accounts payable to affiliatesas of March 31, 2009 and December 31, 2008 also included $0 and$144,789, respectively, for the unpaid portion of the 15% management fee dueReef for organization and offering costs, including sales commissions. Themanagement fee is payable in two parts. Reef initially received an amount notto exceed 13.5% of the total offering proceeds to recover actual commissionsand organization and offering costs. The balances payable at March 31,2009 and December 31, 2008 represent the unpaid portion of the managementfee in excess of actual commissions and organization and offering costs, andare paid to Reef from the oil and gas cash flows available for partnerdistributions, at a rate not to exceed $1 million per year. During 2007, thePartnership reimbursed $600,000 of this amount to Reef. The Partnershipreimbursed this amount to Reef at a rate of $50,000 per month, and completedpayment of the December 31, 2008 balance due during March 2009.

 

**4.Commitments and Contingencies**

 

The Partnership is notcurrently involved in any legal proceedings.

 

**5.  Partnership Equity**

 

Information regarding thenumber of units outstanding and the net income (loss) per type of Partnershipunit for the three month periods ended March 31, 2009 and 2008 is detailedbelow:

 

For the threemonths ended March 31, 2009

 
| **Type of Unit**                | ** ** | **Number of  Units** | ** ** | **Net loss** | ** ** | **Net loss per  unit** | ** ** |
|---------------------------------|------------|----------------------|------------|--------------|------------|------------------------|------------|
| Managing general  partner units |       | 75.363               |       | $            | (78,685    | )                      | $          | (1,044.08 | ) |
| General partner  units*         |       | 0.000                |       | —       |       | $                      | —     |   |
| Limited partner  units*         |       | 1,431.897            |       | (2,403,207   | )          | $                      | (1,678.34  | ) |
| Total                           |       | 1,507.260            |       | $            | (2,481,892 | )                      |       |   |

 

For the threemonths ended March 31, 2008

 
| **Type of Unit**                | ** ** | **Number of  Units** | ** ** | **Net income** | ** ** | **Net income  per unit** | ** ** |
|---------------------------------|------------|----------------------|------------|----------------|------------|--------------------------|------------|
| Managing general  partner units |       | 75.363               |       | $              | 196,694    |                     | $          | 2,609,96 |   |
| General partner  units*         |       | 1,190.561            |       | 646,844        |       | $                        | 543.31     |   |
| Limited partner  units*         |       | 241.336              |       | 131,120        |       | $                        | 543.31     |   |
|                            |       |                 |       |           |       |                     |       |
| Total                           |       | 1,507.260            |       | $              | 974,658    |                     |       |   |

 

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*   Duringthe third quarter of 2008, all general partner units of the Partnership wereconverted into limited partner units.

 

**Item2.  Management’s Discussion and Analysisof Financial Condition and Results of Operations**

 

The following is a discussion of the Partnership’s financialposition, results of operations, liquidity and capital resources. Thisdiscussion should be read in conjunction with our financial statements and therelated notes thereto, included in the Annual Report.

 

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

 

·                  statementsregarding the state of the oil and gas industry and the opportunity to profitwithin the oil and gas industry, competition, pricing, level of production, orthe regulations that may affect the Partnership;

 

·                  statementsregarding the plans and objectives of Reef for future operations, including,without limitation, the uses of Partnership funds and the size and nature ofthe costs the Partnership expects to incur and people and services thePartnership may employ;

 

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·                  any statementsusing the words “anticipate,” “believe,” “estimate,” “expect” and similar suchphrases or words; and

 

·                  any statementsof other than historical fact.

 

Reef believes that it isimportant to communicate its future expectations to the partners. Forward-looking statements reflect the current view of management with respectto future events and are subject to numerous risks, uncertainties andassumptions, including, without limitation, the risk factors listed in thesection captioned “RISK FACTORS” contained in the Reef Global Ventures IIDrilling Program’s (the “Program”) prospectus and prospectus supplement eachdated July 8, 2005. Although Reef believes that the expectations reflectedin such forward-looking statements are reasonable, Reef can give no assurancethat such expectations will prove to have been correct.  Should any one ormore of these or other risks or uncertainties materialize or should anyunderlying assumptions prove incorrect, actual results are likely to varymaterially from those described herein.  There can be no assurance thatthe projected results will occur, that these judgments or assumptions willprove correct or that unforeseen developments will not occur.

 

Reef does not intend toupdate its forward-looking statements.  All subsequent written and oralforward-looking statements attributable to Reef or persons acting on its behalfare expressly qualified in their entirety by the applicable cautionarystatements.

 

**Overview**

 

Reef Global Energy VI,L.P. is a Nevada limited partnership formed to acquire, explore, develop andproduce crude oil, natural gas, and natural gas liquids for the benefit of itsinvestor partners. The Partnership’s primary purposes are to generate revenuesfrom the production of crude oil and natural gas, distribute cash flow toinvestors, and provide tax benefits to investors. The Partnership purchasedworking interests in twenty developmental prospects. The Partnershipparticipated in the drilling of eight successful developmental wells on eightdevelopmental prospects located in Acadia Parish, Louisiana, Pittsburg County,Oklahoma, and Palo Pinto, Jackson, Harris, Galveston, and Lavaca (twoprospects) County, Texas. Four of the wells located in Jackson and Lavaca (twoprospects) County, Texas and Acadia Parish, Louisiana have ceased production.The Partnership participated in the drilling of eleven unsuccessfuldevelopmental wells on eleven developmental prospects located in West BatonRouge, Acadia, Calcasieu, and Cameron Parish, Louisiana, and in Hardin, Upton,Ector, Jefferson, Lavaca, Reeves, and Dawson County, Texas. The Partnershippurchased a working interest in the Sand Dunes developmental prospect in EddyCounty, New Mexico, and has participated in the drilling of eight unsuccessfuldevelopmental wells on this prospect (see below).

 

The Partnership alsopurchased working interests in fourteen exploratory prospects, and participatedin the drilling of sixteen exploratory and eight developmental on thoseprospects, including the well drilled in March 2009 (see below). The Partnershipparticipated in the drilling of eight successful exploratory wells, sevensuccessful developmental wells, one unsuccessful exploratory well, and oneunsuccessful developmental well on seven exploratory prospects located inTerrebonne and St. Martin Parish, Louisiana, Sterling, Jefferson (twoprospects) and Live Oak County, Texas, and offshore in U.S. Coastal waters inthe Gulf of Mexico. During March 2009, the Partnership participated in thedrilling of an additional exploratory well on the prospect in Live Oak County,Texas which was unsuccessful.  ThePartnership participated in the drilling of seven unsuccessful exploratorywells on seven exploratory prospects located in West Baton Rouge, Beauregard,and Cameron Parish, Louisiana, Brazoria, Lavaca, and San Patricio County,Texas, and offshore in U.S. Coastal waters in the Gulf of Mexico. Of thefifteen successful wells, three wells located in St. Martin and TerrebonneParish, Louisiana and in Live Oak County, Texas have ceased production.

 

Subsequent to completingits drilling phase of operations in the first quarter of 2008, the Partnershiphas drilled two additional wells on one of the Partnership’s exploratoryprospects located in Live Oak County, Texas. One of these wells was successfuland began production operations in November 2008, and the second well wasunsuccessful. These wells are included in the summaries of wells in thepreceding paragraphs. While there are currently no plans to drill anyadditional wells, the Partnership is allowed to borrow funds in accordance withthe Partnership Agreement, or utilize cash flows from successful wells in orderto conduct further development upon prospects initially purchased by anddrilled upon by the Partnership during the drilling phase of operations.

 

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A “prospect” is generallydefined as a contiguous oil and gas leasehold estate, or lesser interest in aleasehold estate, upon which drilling operations may be conducted. A prospectmay be characterized as “exploratory” or “developmental” based upon the type ofwell to be drilled on the prospect. A development well is a well drilled withina proved area of an oil or gas reservoir to the depth of a stratigraphichorizon known to be productive. Generally an exploratory well is any well thatis not a development well, including wells drilled to find and produce crudeoil or natural gas in an unproven area, wells drilled to find a new reservoirin a field previously found to be productive of crude oil or natural gas, orwells drilled to extend a known reservoir. In this Quarterly Report, we use theterm “successful” to refer to wells that are drilled, tested, and eithercapable 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 table belowsummarizes Partnership expenditures at March 31, 2009 by classification ofwell. Drilling, completion, and facilities costs include $303,397 capitalizedas asset retirement cost.

 
| ** **           | ** ** | **Leasehold  Costs** | ** ** | **Drilling,  Completion,  and Facilities  Costs** | ** ** | **Total Costs** | ** ** |
|----------------------|------------|----------------------|------------|---------------------------------------------------|------------|-----------------|------------|
| Developmental  wells |       | $                    | 1,475,808  |                                              | $          | 19,223,651      |       | $ | 20,699,459 |   |
| Exploratory wells    |       | 1,238,624            |       | 11,451,121                                        |       | 12,689,745      |       |
| Unproved  properties |       | 172,930              |       | —                                            |       | 172,930         |       |
| Total                |       | $                    | 2,887,362  |                                              | $          | 30,674,772      |       | $ | 33,562,134 |   |

 

The Partnershipparticipated in the drilling of eight developmental wells on the Sand Dunesprospect located in Eddy County, New Mexico during the fourth quarter of 2007and the first quarter of 2008. Initial testing confirmed the presence of crudeoil and natural gas in all eight wells. However, the field was temporarilyshut-in because of the lack of electric service and because of the high cost oftrucking offsite the salt water volumes associated with the production of thecrude oil and natural gas from the wells. Electrical service to the eight SandDunes wells was connected in September 2008. Based upon initial testing, largerbottom hole pumps were placed below the well perforations in three of the wellsand testing was resumed in late September 2008 to determine the threewells’ commercial productivity. Water continued to be trucked offsite, and RELPapplied for and received a permit which would allow for the conversion of oneof the existing eight Sand Dunes wells into a water disposal well. RELP hasalso explored the possibility of drilling a ninth well as a salt water disposalwell for the field. Testing results on two of the three wells were positive,and salt water production volumes declined as a result of pumping off the wellsusing the larger bottom hole pumps. However, the price of crude oil alsodeclined at a rapid rate while testing was being conducted. In late December 2008two of the three testing wells were shut-in again. Crude oil prices continueddeclining to a level below $40 per barrel. In February 2009, following amechanical failure in the third testing well, RELP, as operator, shut-in thefield. The eight wells cannot be commercially productive without efficient saltwater disposal capabilities, and RELP does not believe any of the optionsregarding salt water disposal are economically viable at current commodityprices. As a result, as of December 31, 2008, the eight Sand Dunes wellswere classified as unsuccessful, and there are no crude oil and natural gasreserves for these wells included in the March 31, 2009 reserveinformation presented in this Quarterly Report. However, RELP has made no plansto plug and abandon the wells at this time, and will continue to monitor andevaluate the economics of the field based upon commodity prices.

 

The Partnership also ownsinterests in unproved property consisting of un-drilled leasehold interest (11potential drilling locations) in the Sand Dunes prospect. The Partnership fullyimpaired this unproved property during the fourth quarter of 2008 based uponthe eight already drilled Sand Dunes wells being classified as unsuccessful at December 31,2008. The Partnership currently has no plans to conduct any drilling operationson this acreage.

 

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**CriticalAccounting Policies**

 

There have been no changes from the Critical Accounting Policiesdescribed in the Annual Report.

 

**Liquidityand Capital Resources**

 

The Partnership wasfunded with initial capital contributions totaling $37,398,898. Reef purchased75.363 general partner units, or 5% of the total units sold, for $1,601,464.Investor partners purchased 1,190.561 units of general partner interest and241.336 units of limited partner interest for $35,797,434. As of September 30,2008, Reef has also contributed $308,756 in connection with its obligation topay 1% of all leasehold, drilling, and completion costs. Organization andoffering costs totaled $5,369,615, leaving capital contributions of $32,338,039available for Partnership activities. As of March 31, 2009, thePartnership has expended $33,258,737 on prospect and property acquisitions,drilling and completion costs in connection with its participation in thedrilling of fifty-one wells and has expended $138,317 on general andadministrative expenses. The total of these expenses is $1,059,015 in excess ofthe capital available for Partnership activities. Expenditures in excess of available capitalare being deducted from Partnership distributions.  At March 31, 2009, the Partnership hadrecovered the entire $1,059,015. The Partnership does not operate in any otherindustry segment, and operates solely in the United States.

 

The Partnership hasworking capital of $891,459 at March 31, 2009. Subsequent to expending theinitial available partner capital contributions on prospect and propertyacquisitions and drilling and completion costs of Partnership wells, thePartnership has minimal working capital, primarily consisting of cash andaccounts receivable from RELP related to oil and gas sales from productiveproperties processed by RELP, which the Partnership uses to pay monthly cashdistributions to investors.

 

**Resultsof Operations**

 

The following is acomparative discussion of the results of operations for the periods indicated.It should be read in conjunction with the condensed financial statements andthe related notes to the condensed financial statements included in thisQuarterly Report.

 

The following tableprovides information about sales volumes and crude oil and natural gas pricesfor the periods indicated. Equivalent barrels of oil (“EBO”) are computed byconverting 6 MCF of natural gas to 1 barrel of crude oil.

 
| ** **                      | ** ** | **For the three months  ended March 31,** | ** ** |
|---------------------------------|------------|------------------------------------------------|------------|
| ** **                      | ** ** | **2009**                                       | ** ** | **2008** | ** ** |
| Sales volumes:                  |       |                                           |       |   |   |
| Oil (Barrels)                   |       | 9,984                                          |       | 6,272 |   |
| Natural gas  (MCF)              |       | 190,933                                        |       | 153,878 |   |
| EBO                             |       | 41,806                                         |       | 31,918 |   |
|                            |       |                                           |       |   |   |
| Average sales  prices received: |       |                                           |       |   |   |
| Oil (Barrels)                   |       | $                                              | 34.68      |   | $ | 94.26 |   |
| Natural gas  (MCF)              |       | $                                              | 4.65       |   | $ | 8.64 |   |

 

The Partnership hadseventeen productive wells during the first quarter of 2009 and 2008. One ofthe seventeen productive wells during the first quarter of 2008 ceasedproduction in January 2008. The Rob L RA SUA CL&F #1 (“Gumbo II”) wellbegan production operations in May 2008, and is included in the productivewell count for the first quarter of 2009. The Gumbo II well is one of three significantwells in which the Partnership owns a working interest, and sales volumes fromthis well more than offset the volumes from the well that ceased production in January 2008and the declining production volumes from all of the other Partnership wells.Management expects overall production volumes sold during 2009 to approximate2008 volumes as a result of the Gumbo II well producing for the entire calendaryear of 2009. The well began production during May 2008, and did not reachfull production capacity until July 2008. However, we anticipate that thePartnership has already achieved its peak production levels, and although weexpect overall volumes sold during 2009 to approximate 2008 volumes, we expectindividual quarterly volumes to decrease throughout the remainder of 2009.

 

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Sales volumes from thePartnership’s three significant wells, the Gumbo II, the HBR A Big Gas Unit (“HBRA”) and the ST 278L/279L #1 (“Dolphin B”) totaled 8,329 barrels of crude oiland 138,725 MCF of natural gas, or 83.4% and 72.7% of first quarter 2009volumes, respectively. During the first quarter of 2008, the HBR A and theDolphin B volumes totaled 3,364 barrels of crude oil and 90,365 MCF of naturalgas, or 53.6% and 58.7% of first quarter 2008 volumes, respectively. Whileoverall sales volumes were higher during the first quarter of 2009 compared tothe first quarter of 2008, revenues fell by 35.7% due to the steep decline inthe average sales prices of crude oil and natural gas from the first quarter of2008 to the first quarter of 2009, as shown in the table above. While crude oilprices have begun to move upward beginning with March 2009 sales volumes,gas prices have declined subsequent to March 31, 2009, and the Partnershipalso expects to incur a net loss for the second quarter of 2009.

 

Net proved crude oil andnatural gas reserves of the Partnership at March 31, 2009 and 2008 aredetailed below. Net proved crude oil and natural gas reserves at March 31,2008 include proved developed non-producing reserves from the Partnership’seight Sand Dunes wells which were declared unsuccessful during the fourthquarter of 2008. Net proved non-producing reserves attributable to the SandDunes wells in the March 2008 reserve study were 36,708 barrels of crudeoil and 84,260 MCF of natural gas.  Netproved crude oil and natural gas reserves at March 31, 2009 and 2008include only those quantities that we expect to recover commercially usingcurrent prices, costs, existing regulatory practices, and technology as of thedate indicated. Therefore, any changes in future prices, costs, regulations,technology or other unforeseen factors could materially increase or decreasethe proved reserve estimates. No additional development costs are required torecover these proved reserves at March 31, 2009. All of the Partnership’sreserves are located in the United States.

 

The Partnership hassixteen productive wells as of March 31, 2009. The Partnership’s reservesare highly concentrated in three of these wells. These three wells are theGumbo II well in Terrebonne Parish, Louisiana, the Dolphin B well in the Gulfof Mexico, and the HBR A well in Galveston County, Texas. These three wellshave total estimated proved reserves of 79,114 barrels of crude oil and1,661,647 MCF of natural gas at March 31, 2009.  Using a conversion factor of 6 MCF to 1barrel of oil, these three wells have approximately 82.3% of total Partnershipreserves at March 31, 2009.

 

During the first quarterof 2009, the Partnership recorded property impairment expense of provedproperties totaling $2,417,333 as a result of the net capitalized costs ofproved oil and gas properties exceeding the sum of estimated future netrevenues from proved reserves, using prices in effect at the end of the periodheld constant and discounted at 10%. The decline in commodity prices hasresulted in shorter estimated economic lives for Partnership properties, whichhas decreased both reserve estimates and the corresponding future net revenuesexpected from Partnership properties.

 
| **Net proved reserves** | ** ** | **Oil (BBL)** | ** ** | **Gas (MCF)** | ** ** |
|-------------------------|------------|---------------|------------|---------------|------------|
| March 31,  2009    |       | 91,492        |       | 2,047,162     |       |
| March 31,  2008    |       | 177,679       |       | 3,461,793     |       |

 

**Threemonths ended March 31, 2009 compared to the three months ended March 31,2008**

 

The Partnership had a netloss of $2,481,888 for the three month period ended March 31, 2009,compared to net income totaling $974,658 for the three month period ended March 31,2008.

 

The Partnership incurredno property impairment expense during the three month period ended March 31,2008. However, the decline in oil and gas prices has resulted in impairmentexpense of proved properties totaling $2,417,333 for the quarter ending March 31,2009. Depletion expense also increased from $494,688 for the first quarter of2008 to $802,032 for the first quarter of 2009, as increased sales volumes anddecreased reserves for the first quarter of 2009 led to a higher overalldepletion rate. The net effect of these two non-cash items was additionalexpense of approximately $2,725,000 incurred during the first quarter of 2009.

 

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While overall salesvolumes increased during the first quarter of 2009, primarily as a result ofthe Gumbo II well which did not produce during the first quarter of 2008, therewere sharp declines in the sales prices received for the Partnership’sproduction. The average oil price received on a comparative basis declined from$94.26 per barrel of crude oil during the first quarter of 2008 to $34.68 perbarrel during the first quarter of 2009, a drop of 63.2%. Gas prices also declinedsignificantly; from an average price of $8.64 per MCF of natural gas producedduring the quarter ended March 31, 2008 to $4.65 per MCF for the quarterended March 31, 2009, a decline of 46.2%. Overall the Partnership’s oiland gas sales revenues dropped by approximately $686,000, or 35.7% for thequarter ended March 31, 2009. This loss of revenues and the impairmentexpense required as a result of the lower crude oil and natural gas prices werethe two primary differences between the comparative quarters. While oil pricesbegan an upward movement beginning with March 2009 oil sales, gas priceshave continued to decline, and the Partnership expects to incur a loss duringthe second quarter based upon current prices.

 

Lease operating costsincreased during the quarter ended March 31, 2009 compared to the quarterended March 31, 2008. Operating costs for the Gumbo II well, which did notproduce during the first quarter of 2008, were approximately $66,000.  Partially offsetting this increase was areduction of approximately $22,300 in lease operating costs as a result of theSand Dunes prospect being shut-in during February 2009. The costs ofelectricity and salt water disposal during the testing of the wells in 2008caused higher first quarter operating expenses for the Sand Dunes wells.

 

General andadministrative costs increased from $115,824 incurred during the first quarterof 2008 to $154,233 incurred during the first quarter of 2009. The increase isprimarily the result of a change in the method for allocating overhead topartnerships sponsored by Reef. Effective April 1, 2008 Reef  implemented a new method for allocatingoverhead that takes actual overhead and allocates it based upon the summationof revenues, expenses, and actual capital costs incurred. Under the priormethod of allocating overhead, not all allocable general and administrativeexpenses were charged to the partnerships sponsored by Reef. The administrativeoverhead charge to the Partnership for the quarter ended March 31, 2009was $137,862, compared to $105,677 for the quarter ended March 31, 2008.

 

**Item 3.Quantitative and Qualitative Disclosures About Market Risk**

 

Not Applicable.

 

**Item 4T. Controls and Procedures**

 

**Evaluation of Disclosure Controls and Procedures**

 

As the managing generalpartner of the Partnership, Reef maintains a system of controls and proceduresdesigned to provide reasonable assurance as to the reliability of the financialstatements and other disclosures included in this report, as well as tosafeguard assets from unauthorized use or disposition. The Partnership, underthe supervision and with participation of its management, including theprincipal executive officer and principal financial officer, evaluated theeffectiveness of its “disclosure controls and procedures” as such term isdefined 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 thisQuarterly Report. Based on that evaluation, the principal executive officer andprincipal financial officer have concluded that the Partnership’s disclosurecontrols and procedures are effective to ensure that information required to bedisclosed by the Partnership in reports that it files or submits under theExchange Act is recorded, processed, summarized, and reported within the timeperiods specified in Securities and Exchange Commission rules and forms,and includes controls and procedures designed to ensure that informationrequired to be disclosed by us in such reports is accumulated and communicatedto our management, including the principal executive officer and principalfinancial officer, as appropriate to allow timely decisions regarding financialdisclosure.

 

**Changesin Internal Controls**

 

Therehave not been any changes in the Partnership’s internal controls over financialreporting during the fiscal quarter ended March 31, 2009 that havematerially affected, or are reasonably likely to materially affect, thePartnership’s internal control over financial reporting.

 

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**PART II — OTHER INFORMATION**

 

**Item 1. Legal Proceedings**

 

None.

 

**Item 2. Unregistered Sales of Equity Securities and Use of Proceeds**

 

**Use ofProceeds**

 

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

 

The Partnershipregistered a total of 400 units of limited partner interests and 1,600 units ofgeneral partner interests. The aggregate offering amount registered was$50,000,000. During the offering period that terminated on October 31,2005, the Partnership sold 1,431.897 units to investor partners, consisting of241.336 units of limited partner interest and 1,190.561 units of additionalgeneral partner interest. Reef purchased 75.363 general partner units, equaling5.00% of the total Partnership units sold. The Partnership did not sell theremaining registered units. Total offering proceeds were $37,398,898. Reef isalso obligated to contribute 1% of all leasehold, drilling, and completioncosts as incurred. At March 31, 2009, Reef had contributed $308,756 to thePartnership in connection with this obligation.

 

All units except thosepurchased by Reef paid a 15% management fee to Reef to pay for the Partnershiporganization and offering costs, including sales commissions. These coststotaled $5,369,615, leaving capital contributions of $32,338,039 available forPartnership oil and gas operations. As of March 31, 2009, the Partnershiphad expended $33,258,737 on property acquisitions and prepayments and $138,317on pre-production general and administrative expenses. Expenditures in excessof available capital began being deducted from Partnership distributions in August 2008.

 

**Item 3. Default Upon Senior Securities**

 

None.

 

**Item 4. Submission of Matters to a Vote of Security Holders**

 

None.

 

**Item 5. Other Information**

 

None.

 

**Item 6. Exhibits**

 
| Exhibits |   |                                                                                                               |
|----------|--------|--------------------------------------------------------------------------------------------------------------------|
|     |   |                                                                                                               |
| 31.1     |   | Certification of  Principal Executive Officer pursuant to Section 302 of the  Sarbanes-Oxley Act of 2002.     |
|     |   |                                                                                                               |
| 31.2     |   | Certification of  Principal Financial Officer pursuant to Section 302 of the  Sarbanes-Oxley Act of 2002.     |
|     |   |                                                                                                               |
| 32.1     |   | Certification of the  Principal Executive Officer pursuant to Section 906 of the  Sarbanes-Oxley Act of 2002. |
|     |   |                                                                                                               |
| 32.2     |   | Certification of the  Principal Financial Officer pursuant to Section 906 of the  Sarbanes-Oxley Act of 2002. |

 

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**SIGNATURES**

 

Pursuant to therequirements of the Securities Exchange Act of 1934, the registrant has dulycaused this report to be signed on its behalf by the undersigned, thereuntoduly authorized.

 
|                                 | REEF GLOBAL  ENERGY VI, L.P. |
|--------------------------------------|------------------------------|
|                                 |                         |   |
|                                 | By:                          | Reef  Oil & Gas Partners, L.P. |
|                                 |                         | Managing General  Partner |
|                                 |                         |   |
|                                 | By:                          | Reef  Oil & Gas Partners, GP, LLC |
|                                 |                         |   |
|                                 |                         |   |
| Dated:   May 14, 2009 | By:                          | /s/ Michael J.  Mauceli |
| ** **                           | ** **                   | **Michael  J. Mauceli** |
|                                 |                         | Manager and  Member |
| * *                             | * *                     | *(principal  executive officer)* |
|                                 |                         |   |
|                                 |                         |   |
| Dated:   May 14, 2009 | By:                          | /s/ L. Mark  Price |
| ** **                           | ** **                   | **L. Mark  Price** |
|                                 |                         | Chief Financial  Officer |
|                                 |                         | Reef  Exploration, L.P. |
| * *                             | * *                     | *(principal financial and accounting  officer)* |

 

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**EXHIBIT INDEX**

 
| **Exhibits** | ** ** | ** **                                                                                                         |
|--------------|------------|--------------------------------------------------------------------------------------------------------------------|
|         |       |                                                                                                               |
| 31.1         |       | Certification of  Principal Executive Officer pursuant to Section 302 of the  Sarbanes-Oxley Act of 2002.     |
|         |       |                                                                                                               |
| 31.2         |       | Certification of  Principal Financial Officer pursuant to Section 302 of the  Sarbanes-Oxley Act of 2002.     |
|         |       |                                                                                                               |
| 32.1         |       | Certification of the  Principal Executive Officer pursuant to Section 906 of the  Sarbanes-Oxley Act of 2002. |
|         |       |                                                                                                               |
| 32.2         |       | Certification of the  Principal Financial Officer pursuant to Section 906 of the  Sarbanes-Oxley Act of 2002. |

 

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