UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

___________________

FORM 10-Q

x QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 ~~For the Quarterly Period Ended March 31, 2010 or o TRANSITION REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the Transition Period from ________ to ________~~

For the Quarterly Period Ended June 30, 2010

¨	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: 333-93399-04

___________________

REEF GLOBAL ENERGY IV, L.P.

(Exact name of registrant as specified in its charter)

Nevada (State or other jurisdiction of incorporation or organization)	20-1654113 (I.R.S. employer identification no.)
Nevada	20-1654113
1901 N. Central Expressway, Suite 300 Richardson, Texas (Address of principal executive offices)	75080-3610 (Zip code)
(State or other jurisdiction of	(I.R.S. employer
(972)-437-6792
incorporation or organization)	identification no.)
(Registrant’s telephone number, including area code)
1901 N. Central Expressway, Suite 300	75080-3610
Richardson, Texas	(Zip code)
(Address of principal executive offices)

~~Indicate by check mark whether the registrant~~ (1972) 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 -437-6792

~~Indicate~~Registrant’s telephone ~~by check mark whether the registrant has submitted electronically and posted on its corporate Web site~~number, ifincluding ~~any,~~area every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes o No ocode

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 ¨

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

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

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

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

As of August ~~May 12~~13, 2010, the registrant had 25.028 units of general partner interest held by the managing general partner, and 474.972 units of limited partner interest outstanding.

Reef Global Energy IV, L.P.

Form 10-Q Index

PART I – FINANCIAL INFORMATION
PART I — FINANCIAL INFORMATION			1
ITEM 1.	~~Financial Statements (Unaudited)~~	3Financial Statements (Unaudited)	1
	~~Condensed Balance Sheets~~	3Condensed Balance Sheets	1
	~~Condensed Statements of Operations~~	4Condensed Statements of Operations	2
	~~Condensed Statements of Cash Flows~~	5Condensed Statements of Cash Flows	3
	~~Notes to Condensed Financial Statements~~	6Notes to Condensed Financial Statements	4
ITEM 2.	~~Management’s Discussion and Analysis of Financial Condition and Results of Operations~~	10Management’s Discussion and Analysis of Financial Condition and Results of Operations	7
ITEM 3.	~~Quantitative and Qualitative Disclosures About Market Risk~~	13Quantitative and Qualitative Disclosures About Market Risk	12
ITEM 4T.	~~Controls and Procedures~~	13Controls and Procedures	12
PART II – OTHER INFORMATION
PART II — OTHER INFORMATION			12
ITEM 1.	~~Legal Proceedings~~	14Legal Proceedings	12
ITEM 1A.	~~Risk Factors~~	14Risk Factors	12
ITEM 2.	~~Unregistered Sales of Equity Securities and Use of Proceeds~~	14Unregistered Sales of Equity Securities and Use of Proceeds	12
ITEM 3.	~~Default Upon Senior Securities~~	14Default Upon Senior Securities	12
ITEM 4.	~~(Removed and Reserved)~~	14(Removed and Reserved)	13
ITEM 5.	~~Other Information~~	14Other Information	13
ITEM 6.	~~Exhibits~~	14Exhibits	13
Signatures		15	14

2ii

PART I – - FINANCIAL INFORMATION

Item 1. Financial Statements

Reef Global Energy IV, L.P.

Condensed Balance Sheets

	March 31,			December 31,
	June 30,			December 31,
	2010			2009
	(Unaudited)
Assets
Current assets:
Cash and cash equivalents	$	92,~~001~~096		$	91,957
Total current assets		92,~~001~~096			91,957
Oil and gas properties, full cost method of accounting:
Proved properties, net of accumulated depletion of $8,621,675 and $8,581,474		100,700			140,593
Proved properties, net of accumulated depletion of $8,629,828 and $8,581,474		92,256			140,593
Net oil and natural gas properties		~~100~~92,~~700~~256			140,593
Total assets	$	~~192~~184,~~701~~352		$	232,550
Liabilities and partnership equity
Current liabilities:
Accounts payable	$	423		$	1,017
Accounts payable to affiliates		5455,~~547~~998			61,548
Total current liabilities		5456,~~970~~421			62,565
Long-term liabilities:
Asset retirement obligation		60,~~906~~915			93,805
Total long-term liabilities		60,~~906~~915			93,805
Partnership equity:
Limited partners		(4549,~~940~~026	)		(52,528	)
Managing general partner		~~122~~116,~~765~~042			128,708
Partnership equity		7667,~~825~~016			76,180
Total liabilities and partnership equity	$	~~192~~184,~~701~~352		$	232,550

See accompanying notes to condensed financial statements.

Reef Global Energy IV, L.P.

Condensed Statements of Operations

(Unaudited)

	For the three months ended March 31,
	For the three months ended June 30						For the six months ended June 30
	2010			2009			2010			2009
Revenues	$	5553,~~629~~882		$	3137,~~840~~467		$	109,511		$	69,307
Costs and expenses:
Lease operating expenses		155,~~589~~310			2014,~~052~~143			20,899			34,195
Production taxes		1(5,~~160~~744	)		23,~~451~~139			(4,584	)		5,590
Depreciation, depletion and amortization		78,~~958~~153			1312,~~226~~245			16,111			25,471
Property impairment		--—			~~5,511~~—			—			5,511
Accretion of asset retirement obligation		~~565~~9			~~1,264~~537			574			1,801
General and administrative		2956,~~820~~058			2243,~~555~~087			85,878			65,642
Total costs and expenses		5563,~~092~~786			6573,~~059~~151			118,878			138,210
Income (loss) from operations		537			(33,219	)
Loss from operations		(9,904	)		(35,684	)		(9,367	)		(68,903	)
Other income:
Interest income		~~107~~95			~~266~~211			202			477
Total other income		~~107~~95			~~266~~211			202			477
Net income (loss)	$	644		$	(32,953	)
Net loss	$	(9,809	)	$	(35,473	)	$	(9,165	)	$	(68,426	)
Net income per limited partner unit	$	13.87		$	5.46
Net income (loss) per limited partner unit	$	(6.50	)	$	(53.71	)	$	7.37		$	(48.25	)
Net loss per managing general partner unit	$	(~~237~~268.4559	)	$	(~~808~~397.9693	)	$	(506.03	)	$	(1,206.89	)

See accompanying notes to condensed financial statements.

Reef Global Energy IV, L.P.

Condensed Statements of Cash Flows

(Unaudited)

	For the three months ended March 31,
	For the six months ended June 30,
	2010			2009
Operating Activities
Net income (loss)	$	644		$	(32,953	)
Net loss	$	(9,165	)	$	(68,426	)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Adjustments to reconcile net loss to net cash provided by operating activities:
Plugging and abandonment costs paid from asset retirement obligation		(1,219	)		(412,~~133~~396	)
Adjustments for non-cash transactions:
Depreciation, depletion and amortization		716,~~958~~111			1325,~~226~~471
Property impairment		--—			5,511
Accretion of asset retirement obligation		~~565~~574			1,~~264~~801
Changes in operating assets and liabilities:
Accounts receivable from affiliates		--			(9,594	)
Accounts payable		(594	)		2,387
Prepaid expenses		--			(8,769	)
Accounts payable to affiliates		(5,550	)		45,962
Accounts payable		(594	)		1,260
Net cash provided by operating activities		157			310
Accounts payable to affiliates		(7,001	)		24,920
Net cash provided by (used in) operating activities		353			(9,268	)
Investing Activities
Property acquisition and development		(~~309~~18	)		--—
Net cash used in investing activities		(~~309~~18	)		--—
Financing Activities
Partner capital contributions		--—			9,504
Partner distributions		--—			(24,250	)
Net cash used in financing activities		--—			(14,746	)
Net increase (decrease) in cash and cash equivalents		44139			(2414,~~014~~436	)
Cash and cash equivalents at beginning of period		91,957			106,454
Cash and cash equivalents at end of period	$	92,~~001~~096		$	8292,~~440~~018
Supplemental disclosure of non-cash investing transactions:
Property additions included in accounts payable to affiliates	$	--—		$	514,~~600~~066
Adjustment to asset retirement obligation	$	(32,625	)	$	--—

See accompanying notes to condensed financial statements.

~~March~~Reef Global 31Energy IV, ~~2010~~L.P.

Notes to Condensed Financial Statements (unaudited)

June 30, 2010

1. Organization and Basis of Presentation

The financial statements of Reef Global Energy IV, L.P. (the “Partnership”) have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”). Certain information and footnote disclosure normally included in annual financial statements prepared in accordance with accounting principles generally accepted in the United States have been condensed or omitted pursuant to those rules and regulations. We have recorded all transactions and adjustments necessary to fairly present the financial statements included in this Quarterly Report on Form 10-Q (this “Quarterly Report”). The adjustments are normal and recurring. The following notes describe only the material changes in accounting policies, account details, or financial statement notes during the first ~~three~~six months of 2010. Therefore, please read these condensed financial statements and notes to condensed financial statements together with the audited financial statements and notes to financial statements contained in the Partnership’s Annual Report on Form 10-K for the period ended December 31, 2009 (the “Annual Report”).

Going Concern

The accompanying financial statements have been prepared assuming the Partnership is a going concern, which assumption contemplates the realization of assets and satisfaction of liabilities in the normal course of business. The Partnership has suffered losses from operations that have utilized a major portion of partnership equity. While the Partnership appears to have adequate liquidity at June ~~March 31~~30, 2010, there can be no assurance that such liquidity will remain sufficient.

These factors raise substantial doubt about the Partnership’s ability to continue as a going concern. The financial statements do not include any adjustments relating to the recoverability and classification of recorded asset amounts or the amount of liabilities that might be necessary should the Partnership be unable to continue in existence.

The managing general partner is considering several options related to the Partnership, including the possible sale of marketable assets, as a result of the recurring losses incurred over the past several years, the erosion of partnership equity, and the lack of significant cash flows from operations.

2. Summary of Accounting Policies

Oil and Gas Properties

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

In applying the full cost method at ~~March~~June 3130, 2010, the Partnership performs a quarterly ceiling test on the capitalized costs of oil and gas properties, whereby the capitalized costs of oil and gas properties are limited to the sum of the estimated future net revenues from proved reserves using prices that are the 12-month un-weighted arithmetic average of the first-day-of-the-month price for crude oil and natural gas held constant and discounted at 10%, plus the lower of cost or estimated fair value of unproved properties, if any. If capitalized costs exceed the ceiling, an impairment loss is recognized for the amount by which the capitalized costs exceed the ceiling, and is shown as a reduction of oil and gas properties and as property impairment expense on the Partnership’s statements of operations. No gain or loss is recognized upon sale or disposition of oil and gas properties, unless such a sale would significantly alter the rate of depletion and amortization. During the three month periods ended ~~March~~June 3130, 2010 and 2009, the Partnership recognized no property impairment expense of proved properties. During the six month periods ended June 30, 2010 and 2009, the Partnership recognized property impairment expense of proved properties totaling $0 and $5,511, respectively.

Estimates of Proved Oil and Gas Reserves

Estimates of the Partnership’s proved reserves at ~~March~~June 3130, 2010 and December 31, 2009 have been prepared and presented in accordance with new SEC rules and accounting standards. These new rules are effective for fiscal years ending on or after December 31, 2009, and require SEC reporting entities to prepare their reserve estimates using revised reserve definitions and revised pricing based upon the un-weighted arithmetic average of the first-day-of-the-month commodity prices over the preceding 12-month period and current costs. Future prices and costs may be materially higher or lower than these prices and costs, which would impact the estimate of reserves and future cash flows.

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

Restoration, Removal, and Environmental Liabilities

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

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

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 six ~~three~~ months ended ~~March~~June 3130, 2010 and the year ended December 31, 2009.

	Three months ended March 31, 2010			Year ended December 31, 2009
	Six months ended June 30, 2010			Year ended December 31, 2009
Beginning asset retirement obligation	$	93,805		$	122,213
Accretion expense		~~565~~574			2,905
Retirement related to property abandonment and restoration		(1,219	)		(31,313	)
Retirement related to disposition of interest in property		(32,245	)		--—
Ending asset retirement obligation	$	60,~~906~~915		$	93,805

Fair Value of Financial Instruments

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

Reclassifications

Certain information provided for prior years has been reclassified to conform to the current year presentation adopted as of ~~March~~December 31, ~~2010~~2009.

Recently Adopted Accounting Pronouncements

Modernization of Oil and Gas Reporting

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

Accounting Standards Codification

In June 2009, the FASB issued guidance on the accounting standards codification and the hierarchy of generally accepted accounting principles. The accounting standards codification is intended to be the source of authoritative US GAAP and reporting standards as issued by the FASB. Its primary purpose is to improve clarity and use of existing standards by grouping authoritative literature under common topics. The accounting standards codification is effective for financial statements issued for interim and annual periods ending after September 15, 2009. The Partnership now describes the authoritative guidance used within the footnotes but no longer uses numerical references. The accounting standards codification does not change or alter existing US GAAP, and there has been no expected impact on the Partnership’s financial position, results of operations or cash flows.

Fair Value Measurement of Liabilities

In August 2009, the FASB issued new guidance for the accounting for the fair value measurement of liabilities. The new guidance provides clarification that in certain circumstances in which a quoted price in an active market for the identical liability is not available, a company is required to measure fair value using one or more of the following valuation techniques: the quoted price of the identical liability when traded as an asset, the quoted prices for similar liabilities or similar liabilities when traded as assets, and/or another valuation technique that is consistent with the principles of fair value measurements. The new guidance is effective for interim and annual periods beginning after August 27, 2009. The new guidance did not have a material effect on the Partnership’s results of operations, financial position or liquidity.

Subsequent Events

In May 2009, the FASB issued new guidance on accounting for subsequent events. This guidance established general standards of accounting for and disclosure of events that occur after the balance sheet date but before financial statements are issued or are available to be issued. This guidance is effective for interim and annual reporting periods ending after June 15, 2009. The Partnership adopted the provisions of this guidance for the period ended June 30, 2009. In February 2010, the FASB issued an update to this guidance. Among other provisions, this update provides that an entity that is a SEC filer is not required to disclose the date through which subsequent events have been evaluated. The Partnership adopted the provisions on its effective date of February 24, 2010. There was no impact on the Partnership’s operating results, financial position or cash flows.

8Fair Value Measurements

In January 2010, the FASB issued new guidance related to improving disclosures about fair value measurements. This guidance requires separate disclosures of the amounts of transfers in and out of Level 1 and Level 2 fair value measurements and a description of the reason for such transfers. In the reconciliation for Level 3 fair value measurements using significant unobservable inputs, information about purchases, sales, issuances and settlements shall be presented separately. These disclosures are required for interim and annual reporting periods effective January 1, 2010, except for the disclosures related to the purchases, sales, issuances and settlements in the roll forward activity of Level 3 fair value measurements, which are effective on January 1, 2011. This guidance was adopted on January 1, 2010 for Level 1 and Level 2 fair value measurements and did not impact the Partnership’s operating results, financial position or cash flows or disclosures regarding the fair value of financial instruments.

3. Transactions with Affiliates

The Partnership has no employees. 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 and accounting personnel who administer all of the Partnership’s operations. The Partnership reimburses RELP for technical and administrative services at cost. During the three month periods ended ~~March~~June 3130, 2010 and 2009, the Partnership incurred noadministrative ~~technical~~costs ~~services~~totaling ~~costs~~$10,378 and ~~incurred~~$10,632, respectively, which are included as general and administrative expenses. During the six month periods ended June 30, 2010 and 2009, the Partnership incurred administrative costs totaling $717,~~554~~932 and $1021,~~763~~394, respectively, which are included as general and administrative expenses.

Reef contributed 1% of all leasehold, drilling, and completion costs when incurred during the drilling and completion phases of Partnership operations. Reef contributed $380,694 related to these obligations. Reef also purchased 5.01% of the Partnership units and paid 5.01% of the 99% of these costs paid by the unit holders (4.96%). Reef has no remaining obligations related to these additional costs subsequent to December 31, 2008.6

~~RELP~~Reef contributed ~~processes~~1% ~~joint~~of ~~interest~~all ~~billings~~leasehold, drilling, and ~~revenues~~completion oncosts ~~behalf~~when ofincurred during the drilling and completion phases of Partnership operations. AtReef contributed ~~March 31~~$380,694 ~~2010~~related ~~and~~to ~~December~~these ~~31,~~obligations. Reef ~~2009,~~also purchased 5.01% of the Partnership ~~owed~~units ~~RELP~~and ~~$54,547~~paid ~~and~~5.01% ~~$61,548,~~of ~~respectively,~~the ~~for~~99% ~~joint~~of ~~interest~~these ~~and~~costs ~~technical~~paid ~~service~~by the ~~charges~~unit ~~processed~~holders in(4.96%). ~~excess~~Reef ofhas ~~net~~had ~~revenues~~no remaining obligations related to these additional costs since December 31, 2008.

RELP processes joint interest billings and revenues on behalf of the Partnership. At June 30, 2010 and December 31, 2009, the Partnership owed RELP $55,998 and $61,548, respectively, for joint interest and technical service charges processed in excess of net revenues.

4. Commitments and Contingencies

The Partnership is not currently involved in any legal proceedings.

5. Partnership Equity

Information regarding the number of units outstanding and the net income (loss) per type of Partnership unit for the three and six month periods ended ~~March~~June 3130, 2010 ~~and 2009~~ is detailed below:

For the three months ended ~~March~~June 3130, 2010

Type of Unit	Number of Units		Net ~~income (~~loss)			Net ~~income (~~loss) per unit
Managing general partner units		25.028	$	(56,~~943~~722	)		(~~237~~268.4559	)
Limited partner units		474.972		6(3,~~587~~087	)		13(6.8750	)
Total		500.000	$	~~644~~(9,809	)

For the six ~~three~~ months ended ~~March~~June 3130, ~~2009~~2010

Type of Unit	Number of Units		Net income (loss)			Net income (loss) per unit
Managing general partner units		25.028	$	(2012,~~247~~665	)		(~~808~~506.9703	)
Limited partner units		474.972		~~(12~~3,~~706~~500	)		57.4637
Total		500.000	$	(329,~~953~~165	)

Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.

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

This Quarterly 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 Quarterly Report. Specifically, the following statements are forward-looking:

●· 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.

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

any statements using the words “anticipate,” “believe,” “estimate,” “expect” and similar such phrases or words; and

any statements of other than historical fact.

Reef believes that it is important to communicate its future expectations to the partners. Forward-looking statements reflect the current view of management with respect to future events and are subject to numerous risks, uncertainties and assumptions, including, without limitation, the factors listed in the section captioned “RISK FACTORS” contained in the Partnership’s Annual Report. 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.

Reef, as managing general partner, initially received a 10% interest in the Partnership as compensation for forming the Partnership, and also received a 1% interest in the Partnership as a result of paying 1% of all leasehold, drilling and completion costs. This 11% interest was not represented by Partnership units. In addition, Reef purchased 5.01% of the Partnership units and, therefore, held 5.01% of the 89% interest in the Partnership (4.46%) held by the unit holders. Effective August 1, 2006, Reef reduced the interest it received as compensation for forming the Partnership from 10% to 5%, and effective November 1, 2006 it reduced this interest from 5% to 0%. Therefore, effective November 1, 2006, Reef holds a 1% interest in the Partnership as a result of paying 1% of all leasehold, drilling and completion costs. This 1% interest is not represented by Partnership units. Effective November 1, 2006 Reef holds 5.01% of the 99% interest in the Partnership (4.96%) held by the unit holders.

Overview

Reef Global Energy IV, L.P. is a Nevada limited partnership formed to acquire, explore, develop, and produce crude oil, natural gas, and natural gas liquids for the benefit of its investor partners. The Partnership’s primary purposes are to generate revenues from the production of crude oil and natural gas, distribute cash flow to investors, and provide tax benefits to investors.

The Partnership purchased working interests in eight developmental prospects and participated in the drilling of eight developmental wells on those prospects. The Partnership also purchased working interests in five exploratory prospects and participated in the drilling of five exploratory wells on those prospects. The Partnership also purchased a royalty interest in a field in Louisiana with three productive wells, one of which is still producing as of the date of this report. Drilling operations on these thirteen prospects were completed during February 2006. Six developmental wells were successful, of which one is still productive, and two developmental wells were unsuccessful. One exploratory well was successful and is still productive, and four exploratory wells were unsuccessful. In this Quarterly 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. Since its inception, the Partnership has incurred $8,087,799 of property impairment associated with wells drilled during the drilling phase of operations, and cash flows from successful wells have not been sufficient to provide significant returns to investor partners.

10In August 2006, the managing general partner agreed to pay 100% of the costs for a working interest in a developmental well located in Terrebonne Parish, Louisiana. The well completed drilling operations in May 2007 and was unsuccessful; however, after reviewing the well logs and other geologic data, the wellbore was re-entered during the fourth quarter of 2007 and successfully sidetracked. Drilling operations were finished during February 2008, and the well began producing in commercial quantities on May 2, 2008. Reef paid 100% of the costs associated with the drilling of the unsuccessful well and the subsequent drilling of the successful sidetrack of this well. The depreciation and depletion associated with this well is allocated 100% to the managing general partner, which has resulted in the managing general partner having a disproportionate net loss per unit as shown on the condensed statements of operations.

In August 2006, the managing general partner agreed to pay 100% of the costs for a working interest in a developmental well located in Terrebonne Parish, Louisiana. The well completed drilling operations in May 2007 and was unsuccessful; however, after reviewing the well logs and other geologic data, the wellbore was re-entered during the fourth quarter of 2007 and successfully sidetracked. Drilling operations were finished during February 2008, and the well began producing in commercial quantities on May 2, 2008. Reef paid 100% of the costs associated with the drilling of the unsuccessful well and the subsequent drilling of the successful sidetrack of this well.8

The Partnership has no plans for additional drilling activities. The Partnership does not operate in any other business segment, and operates solely in the United States. Note 1 to the audited financial statements included in the Partnership’s Annual Report included a section regarding the ability of the Partnership to continue as a going concern, due to recurring losses from operations. The managing general partner continues to consider several options for the Partnership, including the possible sale of marketable assets.

Critical Accounting Policies

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

Liquidity and Capital Resources

The Partnership was funded with initial capital contributions totaling $9,924,916. Reef purchased 25.028 limited partner units, or 5.01% of the total units sold, for $425,475. Investor partners purchased 125.000 units of general partner interest and 349.972 units of limited partner interest for $9,499,441. The Partnership held $68,585 of interest income earned during 2004 and 2005 for use in drilling operations. Reef also contributed $273,440 in connection with its obligation to pay 1% of all leasehold, drilling, and completion costs, and to reimburse the Partnership for 100% of the drilling and sidetracking costs of a well in Louisiana for which Reef ispaid ~~paying~~ 100% of the costs. Organization and offering costs totaled $1,424,916, leaving capital contributions of $8,842,025 available for Partnership activities. The Partnership expended $8,640,194 on the drilling of fourteen wells (including the well for which Reef paid 100% of costs) and the purchase of the royalty ~~purchase~~interest described above, and $112,843 on general and administrative expenses during its initial drilling and completion phase of operations. The Partnership has expended $178,~~311~~020 subsequent to its initial drilling and completion phase of operations on workovers and other capital items. Expenditures in excess of available Partnership capital have been recovered from the cash flow from successful wells by reducing Partnership distributions. The Partnership does not operate in any other industry segment, and operates solely in the United States.

The Partnership’s drilling program is complete, and, as a result, no new wells began production operations during this quarter. No Partnership wells ceased production during the quarter. The Partnership currently has ~~four~~interests in four productive wells.

The Partnership has working capital of $3735,~~031~~675 at ~~March~~June 3130, 2010. Subsequent to expending the initial available partner capital contributions on prospect and property acquisitions and drilling and completion costs of partnership wells, the Partnership has minimal working capital, consisting primarily of cash flow from productive properties utilized to pay cash distributions to investors.

During 2009, the Partnership had a net loss and negative cash flow, primarily due to the significant decrease in crude oil and natural gas prices during the first quarter of 2009. The ability of the Partnership to generate positive cash flows during 2010 will primarily depend upon crude oil and natural gas pricing. The Partnership generated a net ~~income~~loss ~~and~~for ~~positive~~the ~~cash~~three ~~flow~~and ~~during~~six ~~the~~month periods ~~first~~ended ~~quarter~~June of30, 2010, however, it had positive cash flows during these same periods. The managing general partner is considering several options related to the Partnership, including the possible sale of marketable assets and dissolution of the Partnership, as a result of the recurring losses incurred over the past several years, the erosion of Partnership equity, and the lack of significant cash flows from operations.

Results of Operations

The following is a comparative discussion of the results of operations for the periods indicated. It should be read in conjunction with the condensed financial statements and the related notes to the condensed financial statements included in this Quarterly Report.

The following table provides information about sales volumes and crude oil and natural gas prices for the periods indicated. Equivalent barrels of oil (“EBO”) are computed by converting 6 MCF of natural gas to 1 barrel of oil.9

	For the three months ended March 31,
	2010		2009
Sales volumes:
Oil (Barrels)		464		433
Natural gas (MCF)		3,733		3,153
Average sales prices received:
Oil (Barrels)	$	70.57	$	35.07
Natural gas (MCF)	$	6.14	$	5.28

The Partnership had four productive wells during the first quarter of 2010 and five productive wells during the first quarter of 2009. The Partnership had two productive wells during the first quarter of 2009 that accounted for 96.7% of the total sales volume for that quarter. During the first quarter of 2010, sales volumes from these two wells increased by approximately 13.1% on an equivalent barrel of oil basis from 2009 levels, and these two wells account for 99.6% of total sales volumes for the first quarter of 2010.

	For the three months ended June 30,				For the six months ended June 30,
	2010		2009		2010		2009
Sales volumes:
Oil (Barrels)		467		472		931		905
Natural gas (Mcf)		4,401		4,053		8,134		7,206

Average sales prices received:
Oil (Barrels)	$	70.55	$	48.99	$	70.56	$	42.33
Natural gas (Mcf)	$	4.76	$	3.54	$	5.39	$	4.30

InThe Partnership ~~January~~had ~~2009,~~interests ~~the~~in ~~SEC~~four ~~adopted~~productive awells ~~new~~as ~~rule~~of ~~related~~June to30, ~~modernizing~~2010, ~~reserve calculation~~ and ~~disclosure~~five productive ~~requirements~~wells ~~for~~as ~~oil~~of ~~and~~June ~~gas companies~~30, ~~which~~2009. ~~became~~The ~~effective~~Partnership ~~prospectively~~had ~~for~~interests ~~annual~~in ~~reporting~~two ~~periods~~wells during ~~ending~~the onthree ormonths ~~after~~ended ~~December~~June 3130, 2009~~. In~~ ~~addition~~that toaccounted ~~expanding~~for ~~the~~94.7% ~~definition~~of ~~and~~the total ~~disclosure~~sales ~~requirements~~volume for ~~crude~~that ~~oil~~quarter. ~~and~~During ~~natural gas reserves,~~ the ~~new~~three ~~rule~~months ~~changes~~ended ~~the~~June ~~requirements~~30, 2010, ~~for~~sales ~~determining~~volumes ~~quantities~~from ofthese ~~crude~~two ~~oil~~wells ~~and~~increased ~~natural~~by ~~gas~~approximately ~~reserves~~9.3% ~~The~~on ~~new~~an equivalent ~~rule~~barrel ~~requires disclosure~~ of ~~crude~~ oil ~~and~~basis ~~natural~~from ~~gas~~2009 ~~proved reserves by significant geographic area~~levels, ~~using~~and ~~the~~these ~~un-weighted~~wells ~~arithmetic~~account ~~average~~for 99.9% of ~~the~~total ~~first-day-of-the-month~~sales ~~commodity~~volumes ~~prices~~for ~~over~~ the ~~preceding~~three ~~12-month~~months ~~period,~~ended ~~rather~~June ~~than end-of-period prices~~30, ~~and~~2010. ~~allows~~The increase ~~the use of reliable technologies to estimate proved crude oil and natural gas reserves if those technologies have been demonstrated to result~~ in ~~reliable~~sales ~~conclusions about reserves~~ volumes. ~~Reserve~~was ~~and~~primarily related ~~information~~to ~~for March 31, 2010 is presented consistent with~~ the ~~requirements~~Partnership’s non-operated ofGumbo ~~the~~II ~~new~~well, ~~rule.~~which ~~The~~did ~~new rule does~~ not ~~allow~~produce ~~prior-year~~at ~~reserve~~full ~~information~~production torates during beApril ~~restated,~~2009 sodue ~~all information related~~ to ~~March~~issues ~~31, 2009 is presented consistent~~ with ~~prior SEC rules for~~ the ~~estimation~~oil ofpipeline, ~~proved~~but ~~reserves.~~did ~~The~~produce ~~effect~~at offull production ~~applying~~rates during the ~~new~~second ~~definition~~quarter of ~~reliable technology and other non-price related aspects of the updated rules did not significantly impact~~ 2010 ~~net proved reserve volumes~~. ~~All of the Partnership’s reserves are located in the United States.~~

~~The~~In January ~~estimated~~2009, ~~net~~the ~~proved~~SEC ~~crude~~adopted ~~oil~~a new rule related to modernizing reserve calculation and ~~natural~~disclosure requirements for oil and gas ~~reserves~~companies, aswhich ofbecame effective ~~March~~prospectively for annual reporting periods ending on or after December 31, ~~2010~~2009. In addition to expanding the definition and ~~2009~~disclosure requirements ~~are~~for ~~summarized~~crude ~~below.~~oil ~~The~~and natural gas reserves, the new rule changes the requirements for determining quantities of ~~proved~~crude oil and natural gas reserves. The new rule requires disclosure of crude oil and natural gas proved reserves ~~discussed~~by significant ingeographic ~~this~~area, ~~section~~using ~~include~~the ~~only~~un-weighted arithmetic average of the first-day-of-the-month ~~amounts~~commodity ~~which~~prices over the ~~Partnership~~preceding ~~reasonably~~12-month ~~expects~~period, rather tothan ~~recover~~end-of-period inprices, and allows the ~~future~~use ~~from~~of ~~known~~reliable technologies to estimate proved crude oil and natural gas ~~reservoirs~~reserves ~~under~~if ~~the~~those ~~current~~technologies ~~economic~~have been ~~and~~demonstrated ~~operating~~to ~~conditions.~~result ~~Proved~~in reliable conclusions about reserves ~~include~~volumes. Reserve ~~only~~and ~~quantities~~related ~~that~~information for June 30, 2010 is presented consistent with the ~~Partnership~~requirements ~~expects~~of tothe ~~recover~~new ~~commercially~~rule. ~~using~~The ~~current~~new ~~prices,~~rule ~~costs~~does not allow prior-year reserve information to be restated, ~~existing~~so ~~regulatory~~all ~~practices~~information related to June 30, ~~and~~2009 ~~technology~~is presented consistent with prior SEC rules for the estimation of proved reserves. The ~~Therefore,~~effect ~~any~~of ~~changes~~applying inthe ~~future~~new ~~prices,~~definition ~~costs,~~of ~~regulations,~~reliable technology orand other non-price ~~unforeseen~~related ~~factors~~aspects ~~could~~of ~~materially~~the ~~increase~~updated orrules ~~decrease~~did ~~the~~not significantly impact 2010 net proved reserve ~~estimates~~volumes. All of the Partnership’s reserves are located in the United States.

Net proved reserves	Oil (BBL)	Gas (MCF)
March 31, 2010	4,221	59,010
March 31, 2009	5,151	72,920

The estimated net proved crude oil and natural gas reserves as of June 30, 2010 and 2009 are summarized below. The quantities of proved crude oil and natural gas reserves discussed in this section include only the amounts which the Partnership reasonably expects to recover in the future from known oil and gas reservoirs under the current economic and operating conditions. Proved reserves include only quantities that the Partnership expects to recover commercially using current prices, costs, existing regulatory practices, and technology. Therefore, any changes in future prices, costs, regulations, technology or other unforeseen factors could materially increase or decrease the proved reserve estimates.

Net proved reserves	Oil (Bbl)	Gas (Mcf)
June 30, 2010	4,019	57,201
June 30, 2009	4,973	70,969

Three months ended ~~March~~June 3130, 2010 compared to the three months ended ~~March~~June 3130, 2009

The Partnership has a net ~~income~~loss of $~~644~~9,809 for the three month period ended ~~March~~June 3130, 2010, compared to a net loss of $3235,~~953~~473 for the three month period ended ~~March~~June 3130, 2009.

The Partnership ~~had~~incurred ~~four~~no ~~productive~~property ~~wells~~impairment ~~during~~expense ~~the first quarter of 2010 and five productive wells~~ during the ~~first~~three ~~quarter~~month period ofended ~~2009.~~June ~~In particular~~30, ~~the~~2010 ~~Partnership~~or ~~had two productive wells during~~ the ~~first~~three ~~quarter~~month ofperiod ~~2009~~ended ~~that~~June ~~accounted for 96.7% of the total sales volume for that quarter. During the first quarter of 2010~~30, ~~sales volumes from these two wells increased by approximately 13~~2009.1% Depletion onexpense andecreased ~~equivalent barrel of oil basis~~ from ~~2009 levels. In addition~~$12,245 ~~sales prices~~ for ~~crude~~the ~~oil~~three ~~rose~~month byperiod ~~101.2%~~ended June 30, 2009 to ~~an average price of~~ $~~70.57~~8,153 for the ~~first~~three ~~quarter~~month ofperiod ~~2010.~~ended ~~Gas~~June ~~prices~~30, ~~rose by 16.3%~~2010, toprimarily anas a ~~average~~result ~~price~~ of ~~$6.14~~the ~~per~~2009 ~~MCF~~property ~~this~~impairment ~~quarter, compared to an average price~~ of $~~5.28~~52,189, ~~received~~which ~~for~~reduced the ~~first~~2010 basis ~~quarter~~ of ~~2009.~~proved ~~As a result, total sales revenues increased by 74~~property.~~7% for the first quarter of 2010.~~

Lease operating expenses decreased from $20,052 during the first quarter of 2009 to $15,589 during the first quarter of 2010. The primary factor in the decrease is decreases in gas marketing costs of approximately $4,500.10

~~General~~The Partnership ~~and~~had ~~administrative~~interests ~~costs~~in ~~increased~~four ~~from~~productive ~~$22~~wells during the three month period ended June 30,~~555~~ ~~incurred~~2010, and five productive wells during the ~~first~~three ~~quarter~~month ofperiod ended June 30, 2009. toIn ~~$29~~particular,~~820~~ ~~incurred~~the Partnership had interest in two productive wells during the ~~first~~three ~~quarter~~month period ended June 30, 2009 that accounted for 94.7% of the total sales volume. During the three month period ended June 30, 2010, sales volumes from these two wells increased by approximately 9.3% on an equivalent barrel of oil basis from 2009 levels. This increase in sales volumes was primarily related to the Partnership’s non-operated Gumbo II well. This well did not produce at full production rates during April 2009 due to issues with the ~~timing~~oil pipeline, but did produce at full production rates during the second quarter of ~~audit~~2010. ~~and~~Also, ~~professional~~the ~~fees~~operator has produced the Gumbo II well at a higher average production rate in 2010 as compared to 2009. ~~The~~ In ~~administrative~~addition, ~~overhead~~sales ~~charge~~prices for crude oil rose by 44.0%, to ~~the~~an ~~Partnership~~average price of $70.55 for the three ~~months~~month period ended ~~March~~June 3130, 2010. Gas ~~decreased~~prices ~~from~~rose $by 34.5%,~~794~~ into an average price of $4.76 per Mcf, compared to an average price of $3.54 received for the three ~~months~~month period ended ~~March~~June 3130, 2009. As toa $5result,~~416~~ total sales revenues increased by 43.8%.

Lease operating expenses decreased from $14,143 during the three month period ended June 30, 2009 to $5,310 during the three month period ended June 30, 2010, primarily due to the sale of the Thomas H Miller #1 well in March 2010. Ad valorem taxes decreased during the comparable periods due to the JM Watson #1 well, which was plugged and abandoned at the end of 2009. In addition, production taxes decreased during the three month period ended June 30, 2010 compared to the three month period ended June 30, 2009 due to an approximate $10,400 adjustment received from the operator of the Gumbo II well. The operator refunded prior production tax payments because the well obtained a severance tax exemption from the state of Louisiana for the period from inception through February 2010.

General and administrative costs increased from $43,087 incurred during the three month period ended June 30, 2009 to $56,058 incurred during the three month period ended June 30, 2010, primarily due to the timing of professional fees. The administrative overhead charge to the Partnership for the three month period ended June 30, 2010 totaled $5,226, an increase from the $4,946 charge for the three month period ended June 30, 2009.

Six months ended June 30, 2010 compared to the six months ended June 30, 2009

The Partnership has net loss of $9,165 for the six month period ended June 30, 2010, compared to a net loss of $68,426 for the six month period ended June 30, 2009.

The Partnership incurred no property impairment expense during the six month period ended June 30, 2010, and $5,511 for the six month period ended June 30, 2009. Depletion expense decreased from $25,471 for the first six months of 2009 to $16,111 for the first six months of 2010, primarily as a result of the 2009 property impairment of $52,189, which reduced the 2010 basis of proved property.

The Partnership had four productive wells during the first six months of 2010, and five productive wells during the first six months of 2009. In particular, the Partnership had two wells during the first six months of 2009 that accounted for 96.4% of the total sales volume. During the first six months of 2010, sales volumes from these wells increased by approximately 23.4% on an equivalent barrel of oil basis from 2009 levels. This increase in sales volumes was primarily related to the Partnership’s non-operated Gumbo II well, which did not produce at full production rates during April 2009 due to issues with the oil pipeline, but did produce at full production rates during the second quarter of 2010. Also, the operator has produced the Gumbo II well at a higher average rate in 2010 as compared to 2009. In addition, sales prices for crude oil rose by 66.7%, to an average price of $70.56 for the first six months of 2010. Gas prices rose by 25.3%, to an average price of $5.39 per Mcf, compared to an average price of $4.30 received for the first six months of 2009. As a result, total sales revenues increased by 58.0% for the first six months of 2010.

Lease operating expenses decreased from $34,195 during the first six months of 2009 to $20,899 during the first six months of 2010, primarily due to on the sale of the Thomas H Miller #1 well in March 2010. In addition, production taxes decreased during the six month period ended June 30, 2010 compared to the six month period ended June 30, 2009 due to an approximate $10,400 adjustment received from the operator of the Gumbo II well. The operator refunded prior production tax payments because the well obtained a severance tax exemption from the state of Louisiana for the period from inception through February 2010.

General and administrative costs increased from $65,642 incurred during the first two quarters of 2009 to $85,878 incurred during the first two quarters of 2010, primarily due to the timing of professional fees. The administrative overhead charge to the Partnership for the six months ended June 30, 2010 decreased from $10,740 in the six months ended June 30, 2009 to $10,642.

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

The Partnership is a “smaller reporting company” as defined by Rule 12b-2 promulgated under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), and as such, is not required to provide the information required under this item.

Item 4T. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

As the managing ~~Managing~~general ~~General~~partner ~~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 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, evaluated the effectiveness of the design and operation of its “disclosure controls and procedures” as such term is defined in Rule 13a-15(e) promulgated under the Exchange Act, as of the end of the period covered by this Quarterly Report. Based on that evaluation, the principal executive officer and principal financial officer 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 SEC 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, as appropriate to allow timely decisions regarding financial disclosure.

Changes in Internal Controls

There have not been any changes in the Partnership’s internal controls over financial reporting during the fiscal quarter ended ~~March~~June 3130, 2010 that have materially affected, or are reasonably likely to materially affect, the Partnership’s internal control over financial reporting.

PART II – OTHER INFORMATION

Item 1. Legal Proceedings

None.

Item 1A. Risk Factors

There were no material changes in the Risk Factors applicable to the Partnership as set forth in the Annual Report.

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

None.

Item 3. Default Upon Senior Securities

None.

Item 4. (Removed and Reserved)

Item 5. Other Information

None.

Item 6. Exhibits

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.

~~31.1 Certification of Principal Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.~~13

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.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

	REEF GLOBAL ENERGY IV, L.P.
	By:	Reef Oil & Gas Partners, L.P. Managing General Partner
	By:	Reef Oil & Gas Partners, GP, LLC, its general partner
Dated: May 12, 2010	By:	/s/ Michael J. Mauceli
		Michael J. Mauceli Manager and Member of the general partner of Reef Oil & Gas Partners, L.P. (Principal Executive Officer)
Dated: May 12, 2010		/s/ Daniel C. Sibley
		Daniel C. Sibley Chief Financial Officer and General Counsel of Reef Exploration, L.P. (Principal Financial and Accounting Officer)

	REEF GLOBAL ENERGY IV, L.P.

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

	By:	Reef Oil & Gas Partners, GP, LLC,
		its general partner

Dated: August 13, 2010	By:	/s/ Michael J. Mauceli
		Michael J. Mauceli
		Manager and Member
		(Principal Executive Officer)

Dated: August 13, 2010	By:	/s/ Daniel C. Sibley
		Daniel C. Sibley
		Chief Financial Officer and General Counsel of
		Reef Exploration, L.P.
		(Principal Financial and Accounting Officer)

EXHIBIT INDEX

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.

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.

Filing Compare · Reef Global Energy IV, L.P.