Edgar Filing: COASTAL CARIBBEAN OILS & MINERALS LTD

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q/A

x	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE

SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2009

¨	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 1-4668

COASTAL CARIBBEAN OILS & MINERALS, LTD.

(Exact name of registrant as specified in its charter)

BERMUDA		NONE
(State or other jurisdiction of		(I.R.S. Employer Identification No.)
incorporation or organization)

Clarendon House, Church Street, Hamilton, Bermuda		HM 11
(Address of principal executive offices)		(Zip Code)

(850) 576-5982

(Registrant's telephone number, including area code)

(Former name, former address and former fiscal year, if changed since last report)

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. T Yes ¨ 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). T 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 definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer o	Accelerated filer o
Non-accelerated filer o (Do not check if smaller reporting company)	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 T No

The number of shares outstanding of the issuer's single class of common stock as of August 14, 2009 was 46,261,604.

EXPLANATORY NOTE

This Amendment on Form 10-Q/A (the “Amendment”) amends our quarterly report for the period ended June 30, 2009, originally filed with the Securities and Exchange Commission (“SEC”) on August 19, 2009 (the “Original Report”). We are filing this Amendment to correct scrivener’s errors in two places in the Original Report.

Specifically, the revised Consolidated Statements of Cash Flows was corrected to reflect entries made on the Consolidated Statement of Operations that were inadvertently omitted from the Original Report. The revised report also includes the results of operations for the six month period ended June 30, 2009, which was inadvertently omitted from Item 2, Management’s Discussion and Analysis of Financial Condition and Results of Operations.

Except for the foregoing, the Amendment speaks as of the filing date of the Original Report and does not update or discuss any other Company developments after the date of the Original Report.

COASTAL CARIBBEAN OILS & MINERALS, LTD.

FORM 10-Q

June 30, 2009

Table of Contents

		Page
	PART I - FINANCIAL INFORMATION

ITEM 1	Financial Statements

	Consolidated balance sheets at June 30, 2009 and December 31, 2008		4

	Consolidated statements of operations for the three and six month periods ended June 30, 2009 and 2008 and for the period from January 31, 1953 (inception) to June 30, 2009		5

	Consolidated statements of cash flows for the six month periods ended June 30, 2009 and 2008 and for the period from January 31, 1953 (inception) to June 30, 2009		6

	Notes to consolidated financial statements		7

ITEM 2	Management's Discussion and Analysis of Financial Condition and Results of Operations		11

ITEM 3	Quantitative and Qualitative Disclosure About Market Risk		16

ITEM 4	Controls and Procedures		16

	PART II - OTHER INFORMATION

ITEM 5	Other Information		18

ITEM 6	Exhibits		19

	Signatures		20

COASTAL CARIBBEAN OILS & MINERALS, LTD.

FORM 10-Q

PART I - FINANCIAL INFORMATION

ITEM 1 - Financial Statements

CONSOLIDATED BALANCE SHEETS

(Expressed in U.S. dollars)

(A Bermuda Corporation)

A Development Stage Company

	June 30,			December 31,
	2009			2008
	(Unaudited)			(Note)
Assets
Current assets:
Cash and cash equivalents	$	2,261		$	752
Prepaid expenses and other		-			-
Total current assets		2,261			752

Certificates of deposit, restricted		85,112			84,765
Petroleum leases		2,221,621			2,200,475
Equipment, net		5,155			6,415

Total assets	$	2,314,149		$	2,292,407

Liabilities and Shareholders’ Equity

Current liabilities:

Accounts payable and accrued liabilities	$	247,728		$	58,885
Notes payable		48,198			-
Amounts due to related parties		944,177			758,021
Total current liabilities		1,240,103			816,906

Shareholders' equity
Common stock, par value $.12 per share:
Authorized - 250,000,000 shares
Outstanding – 46,261,604 shares		5,551,392			5,551,392
Capital in excess of par value		32,139,311			32,139,311
		37,690,703			37,690,703
Deficit accumulated during the development stage		(36,616,657	)		(36,215,202	)
Total shareholders’ equity		1,074,046			1,475,501
Total liabilities and shareholders’ equity	$	2,314,149		$	2,292,407

Note: The balance sheet at December 31, 2008 has been derived from

the audited consolidated financial statements at that date.

See accompanying notes.

COASTAL CARIBBEAN OILS & MINERALS, LTD.

FORM 10-Q

PART I - FINANCIAL INFORMATION

ITEM 1 - Financial Statements

CONSOLIDATED STATEMENTS OF OPERATIONS

(Expressed in U.S. dollars)

(A Bermuda Corporation)

A Development Stage Company

(Unaudited)

	Three months ended June 30,						Six months ended June 30,						For the period from Jan. 31, 1953 (inception) to June 30,
	2009			2008			2009			2008			2009

Interest and other income	$	319		$	1,133		$	347		$	2,373		$	3,984,318
Gain on settlement		-			-			-			-			8,124,016
		319			1,133			347			2,373			12,108,334
Expenses:
Legal fees and costs		37,095			36,953			75,668			77,366			17,647,356
Administrative expenses		82,664			70,323			152,519			158,516			10,997,240
Salaries		31,250			31,250			62,500			62,500			4,333,931
Shareholder communications		13,380			799			14,706			7,160			4,139,727
Goodwill impairment		-			-			-			-			801,823
Write off of unproved properties		-			-			-			-			6,690,752
Exploration costs		-			-			-			-			188,218
Lawsuit judgments		-			-			-			-			1,941,916
Minority interests		-			-			-			-			(632,974	)
Other		-			-			-			-			364,865
Contractual services		96,409			-			96,409			-			2,252,137
		260,798			139,325			401,802			305,542			48,724,991

Income tax benefit		-			-			-			-			-

Net loss	$	(260,479	)	$	(138,192	)	$	(401,455	)	$	(303,169	)

Deficit accumulated during the development stage													$	(36,616,657	)

Weighted average number of Shares outstanding (basic &diluted)		46,261,604			46,261,504			46,261,604			46,237,978

Net loss per share (basic & diluted)	$	(.01	)	$	(.01	)	$	(.01	)	$	(.01	)

See accompanying notes.

COASTAL CARIBBEAN OILS & MINERALS, LTD.

FORM 10-Q

PART I - FINANCIAL INFORMATION

ITEM 1 - Financial Statements

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Expressed in U.S. Dollars)

(A Bermuda Corporation)

A Development Stage Company

(Unaudited)

							For the period from Jan. 31, 1953
	Six months ended						(inception)
	June 30,						To
	2009			2008			June 30, 2009

Operating activities:
Net loss	$	(401,455	)	$	(303,169	)	$	(36,616,657	)
Adjustments to reconcile net loss to net cash used in operating activities:
Gain on settlement		-			-			(8,124,016	)
Goodwill impairment		-			-			801,823
Minority interest		-			-			(632,974	)
Depreciation		1,260			1,260			7,818
Write off of unproved properties		-			-			6,690,752
Common stock issued for services		-			-			119,500
Compensation recognized for stock option grant		-			-			75,000
Recoveries from previously written off properties		-			-			252,173
Net change in:
Prepaid expenses		-			20,027			-
Accounts payable and accrued liabilities		392,485			242,447			1,209,392
Net cash used in operating activities		(7,710	)		(39,435	)		(36,217,189	)

Investing activities:
Additions to oil, gas, and mineral properties net of assets acquired for common stock and reimbursements		(38,632	)		(213,103	)		(6,491,884	)
Well drilling costs		-			-			(1,071,011	)
Sale of unproved nonoperating interests		-			217,820			512,595
Net proceeds from settlement		-			-			8,124,016
Proceeds from relinquishment of surface rights		-			-			246,733
Purchase of certificate of deposit		(347	)		(2,373	)		(139,767	)
Redemption of certification of deposit		-			-			54,655
Purchase of minority interest in CPC		-			-			(801,823	)
Purchase of fixed assets		-			-			(74,623	)
Net cash provided by (used in) investing activities		(38,979	)		2,344			358,891

Financing activities:
Loan proceeds		48,198			-			48,198
Loans from officers		-			-			111,790
Repayment of loans from officers		-			-			(111,790	)
Sale of common stock net of expenses		-			-			30,680,612
Shares issued upon exercise of options		-			7,500			891,749
Sale of shares by subsidiary		-			-			820,000
Sale of subsidiary shares		-			-			3,720,000
Net cash provided by financing activities		48,198			7,500			35,860,559
Net increase (decrease) in cash and cash equivalents		1,509			(29,591	)		2,261
Cash and cash equivalents at beginning of period		752			30,264			-
Cash and cash equivalents at end of period	$	2,261		$	673		$	2,261

See accompanying notes.

COASTAL CARIBBEAN OILS & MINERALS, LTD.

FORM 10-Q

PART I - FINANCIAL INFORMATION

June 30, 2009 (UNAUDITED)

ITEM 1

Financial Statements

Note 1.

Basis of Presentation

The accompanying unaudited consolidated financial statements include Coastal Caribbean Oils & Minerals, Ltd. (“the Company”) and its wholly owned subsidiary, Coastal Petroleum Company (“Coastal Petroleum”) and have been prepared in accordance with generally accepted accounting principles for interim financial information and with the instructions to Form 10-Q and Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by generally accepted accounting principles for complete financial statements. In the opinion of management, all adjustments considered necessary for a fair presentation have been included. All such adjustments are of a normal recurring nature. Operating results for the three and six month periods ended June 30, 2009 are not necessarily indicative of the results that may be expected for the year ending December 31, 2009. For further information, refer to the consolidated financial statements and footnotes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2008. On August 19, 2009, the date the June 30, 2009, interim consolidated financial statements of the Company were issued, the Company evaluated the recognition and disclosure of subsequent events.

Note 2.

Going Concern

As of June 30, 2009, the Company had no revenues, had recurring losses from operations and has had an accumulated deficit during the development stage. The Company's current cash position is not adequate to fund existing operations or exploration and development of its oil and gas properties. Currently, management is actively pursuing funding to allow the Company to undertake exploration efforts on its own. The Company has had contact with several parties interested in investing in the Company so that the Company could explore its leases on its own. In addition, the Company has been in contact with other parties interested in working with the Company, in buying some of the Company’s leases or in buying an interest in those leases. There is no assurance that the Company will be able to obtain any funding, that sufficient funding can be obtained, or that the Company will be able to raise necessary funds through the sale of some of its leases or interests in those leases. These situations raise substantial doubt about the Company's ability to continue as a going concern. These consolidated financial statements do not include any adjustments to reflect the possible future effects on the recoverability and classification of assets or amounts and classification of liabilities, which may result from the outcome of this uncertainty.

Note 3.

Net income (loss) per share

Net income (loss) per share is based upon the weighted average number of common and common equivalent shares outstanding during the period. The Company’s basic and diluted calculations of EPS are the same because the exercise of options is not assumed in calculating diluted EPS, as the result would be anti-dilutive.

COASTAL CARIBBEAN OILS & MINERALS, LTD.

FORM 10-Q

PART I - FINANCIAL INFORMATION

June 30, 2009 (UNAUDITED)

ITEM 1

Financial Statements (Continued)

Note 4.

Unproved Oil, Gas and Mineral Properties

Farm-out Agreements and Drilling Activity

In May 2008, the Company entered an agreement with Cobra Oil and Gas (“Cobra”). Under the agreement, Cobra paid Coastal $180,000 for the option to acquire a half interest in approximately 78,000 acres of Coastal’s Valley County Leases. The agreement allowed the Company to pay its Lease rentals that were due June 1, 2008, and brought in a new party to explore on the Leases. Cobra has until May 2010 to exercise the option by spending $1,000,000 on behalf of the Company, drilling wells on the leases under the agreement. Those leases included approximately 62,000 acres of leases that were formally under an agreement with F-Cross Resources (“F-Cross”) that expired in 2008 and more than 17,000 acres of other leases Coastal held in Valley County.

The Company had previously entered two farm-out agreements with Western Standard Energy Corp. (“Western Standard”) and F-Cross Resources (“F-Cross”), both of which expired in 2008.

Montana Leases

The Company’s primary presence in Montana is in Valley County, where it holds leases covering approximately 35,873 net acres, which are the remaining unexpired leases from those leases the Company acquired in three separate acquisitions between July 2005 and February 2006. The leases acquired in those acquisitions are contiguous to each other and are referred to collectively as “the Valley County Leases.”

The first acquisition of the Valley County Leases was in July 2005, when the Company acquired the rights to drill two 6,500 foot wells to test Mississippian Lodgepole reefs in Valley County, in northeast Montana for a one time fee of $50,000 from an entity controlled by one of the Company’s Directors. That acquisition included a small amount of acreage and the option to drill fifty additional prospects in the Valley County area.

The second acquisition of the Valley County Leases was in November 2005, when the Company acquired a group of oil and gas lease rights to approximately 109,423 net acres in eastern Montana for $1,568,000 from EOG Resources, Inc. and Great Northern Gas Company. These leases are subject to various overriding royalty interests to others ranging up to 19.5%. These leases expire in years through 2014.

The final acquisition of acreage within the Valley County Leases was in February 2006, when the Company acquired additional oil and gas leases in eastern Montana covering 27,740 net acres contiguous to its existing Montana leases. These leases were acquired from the Bureau of Land Management and United States Department of the Interior.

Coastal assigned a 5% overriding royalty interest (before all expenses) in 8/8ths of the oil or natural gas produced from those Valley County Montana leases to a previous lender.

COASTAL CARIBBEAN OILS & MINERALS, LTD.

FORM 10-Q

PART I - FINANCIAL INFORMATION

June 30, 2009 (UNAUDITED)

ITEM 1

Financial Statements (Continued)

Note 4.

Unproved Oil, Gas and Mineral Properties (Continued)

North Dakota Leases

In July 2005, the Company acquired leases to the deeper rights in approximately 21,688 net acres in and near Slope County, North Dakota for a one time fee of $50,000 from an entity controlled by one of the Company’s Directors and the Company has invested some additional funds to geochemically test and high-grade these and other prospects on the leases. Since that time, some of the leases have expired and the Company currently holds leases on approximately 8,748 gross and 8,510 net acres in North Dakota. The Company is obligated to drill a test well on the original leases, totaling 7,031.08 acres, before November 1, 2009, and has the option to drill the remaining Lodgepole Reef prospects on these leases. The Company had intended to team with other entities to share the cost of the initial 9,700 foot test well, the total estimated drilling cost of which is estimated to be $1,500,000, however, it is unlikely that the Company will be able to identify and contract with a team prospect prior to the expiration date. The leases making up the remaining acreage were leased by the Company and have no obligation associated with them. The Company is actively seeking funding sufficient to allow it to explore its leases on its own.

In December 2007, the Company entered a second farm-out agreement with Western Standard. Under the agreement, the Company assigned leases over four of its high-graded Lodgepole Reef prospects to Western Standard in return for $80,000 which the Company received between November 2007 and April 2008, and which was recorded as a reduction in capitalized petroleum lease costs. The Company will also retain a back-in working interest of 20% in the leases after payout on wells drilled by Western Standard on these prospects. Oil For America has agreed to waive the drilling obligation on these four prospects. The Company still retains additional Lodgepole reef prospects on its North Dakota leases that are not covered by this farm-out agreement.

Note 5.

Income Taxes

For the three and six month periods ending June 30, 2009 and 2008, the Company reported a loss for both financial statement reporting and income tax purposes. The Company has provided a 100% valuation allowance on its deferred tax asset as a result of its net operating loss carryforwards. The Company had approximately $10,000,000 in net operating loss carryforwards at December 31, 2008.

Note 6.

Related Party Transactions

Pursuant to a written agreement with respect to the Valley County Leases, the Company uses an entity controlled by an individual who is a shareholder, officer and director of the Company to perform geotechnical analysis of potential drilling sites at a cost of $1,000 per site. The Company paid no amounts to this entity for either of the three and six months ended June 30, 2009, and 2008.

Through May 2009, the Company paid a monthly retainer to the law firm of Angerer & Angerer which had been litigation counsel to the Company for more than twenty-five years and also

COASTAL CARIBBEAN OILS & MINERALS, LTD.

FORM 10-Q

PART I - FINANCIAL INFORMATION

June 30, 2009 (UNAUDITED)

ITEM 1

Financial Statements (Continued)

Note 6.

Related Party Transactions (Continued)

served the Company in that capacity as well as others including general counsel services, management services, public relations, shareholder relations and representing the Company before state and federal agencies for permitting. The principals of the law firm included two individuals who are collectively shareholders, officers and a director of the Company. The Company expensed $60,000 and $72,000 in legal fees for the six months ended June 30, 2009 and 2008, respectively, including $24,000 and $36,000 in legal fees for the three months ended June 30, 2009 and 2008, respectively. The Company owes $300,000 in accrued legal fees to Angerer & Angerer as of June 30, 2009.

Since June 2009, the Company has retained Robert J. Angerer, Sr. as legal counsel. Mr. Angerer has been litigation counsel to the Company for more than twenty-five years and continues to serve the Company in that capacity as well as others including general counsel services, management services and representing the Company before state and federal agencies for permitting. Mr. Angerer, Sr. is also a shareholder, officer and a director of the Company. The Company expensed $11,600 in legal fees to Mr. Angerer, Sr. for the three and six month periods ended June 30, 2009.

The Company also retains Robert J. Angerer, Jr. who serves as the Company’s corporate secretary and handles management services, public relations, shareholder relations and management of the Company’s website. The Company expensed $0 in fees to Mr. Angerer, Jr. for the three and six month periods ended June 30, 2009.

The Company has retained the law firm of Igler & Dougherty, P.A. as securities counsel. One of the Company’s directors is a shareholder in the law firm. The Company has expensed $6,258 and $9,679 in legal fees and costs for the six months ended June 30, 2009 and 2008, respectively, including $2,360 and $5,705 in legal fees for the three months ended June 30, 2009 and 2008, respectively.

Note 7.

Stock Transactions

In March 2008, the Company received $7,500 from the exercise of outstanding stock options for 50,000 shares from Robert J. Angerer, Sr., a vice president and a director of the Company.

Note 8.

Certificates of Deposit – Restricted

The Company has pledged certificates of deposit for pollution bond requirements under three previous well permits.

Note 9.

Notes Payable

The Company borrowed $48,198 from an individual which was used to make annual rental payments on specific leases. The individual was granted a 0.5% royalty interest in the leases for which the borrowed money was used to pay rentals, which are located primarily in the Starbuck prospect area in Montana.

COASTAL CARIBBEAN OILS & MINERALS, LTD.

FORM 10-Q

PART I - FINANCIAL INFORMATION

June 30, 2009

ITEM 2

Management's Discussion and Analysis of Financial Condition and Results of Operations

Forward Looking Statements

Statements included in Management’s Discussion and Analysis of Financial Condition and Results of Operations, which are not historical in nature are intended to be forward looking statements. The Company cautions readers that forward looking statements are subject to certain risks and uncertainties that could cause actual results to differ materially from those indicated in the forward looking statements. Among the risks and uncertainties are: the uncertainty of securing additional funding through the sale of shares of Coastal Petroleum and/or Coastal Caribbean; changes in the income tax laws relating to tax loss carry forwards; the failure of the Company’s test wells to locate oil or gas reserves or the failure to locate oil or gas reserves which are economically feasible to recover; reductions in world wide oil or gas prices; adverse weather conditions; or mechanical failures of equipment used to explore the Company’s leases.

Critical Accounting Policies

The Company follows the full cost method of accounting for its oil and gas properties. All costs associated with property acquisition, exploration and development activities whether successful or unsuccessful are capitalized

The capitalized costs are subject to a ceiling test which basically limits such costs to the aggregate of the estimated present value discounted at a 10% rate of future net revenues from proved reserves, based on current economic and operating conditions, plus the lower of cost or fair market value of unproved properties.

The Company assesses whether its unproved properties are impaired on a periodic basis. This assessment is based upon work completed on the properties to date, the expiration date of its leases and technical data from the properties and adjacent areas.

General

We are an active independent oil and gas exploration company and through our subsidiary, Coastal Petroleum, we hold mineral rights in Montana and North Dakota in the oil producing region known as the Williston Basin. Our objective formations on those leases include the Lodgepole and the Eagle among others. The Company's future growth will be driven primarily by exploration and development activities. Our business strategy is to increase shareholder value by acquiring and drilling reasonably priced prospects that have good potential, whether in the Williston Basin or in other parts of the United States, with the goal of shaping the Company into a producing independent oil and gas firm. We will continue to seek high quality exploration projects with potential for providing long-term drilling inventories that generate high returns.

In Montana, we have obtained the rights to explore for oil and gas in one area which will be our primary area of focus. This primary area is a large assembly of leases covering approximately 35,873 net acres in Valley County, located in northeastern Montana close to known production from a Lodgepole reef.

COASTAL CARIBBEAN OILS & MINERALS, LTD.

FORM 10-Q

PART I - FINANCIAL INFORMATION

June 30, 2009

ITEM 2

Management's Discussion and Analysis of Financial Condition and Results of Operations (Continued)

This area of Montana has a number of other producing formations in addition to the Lodgepole, including the Eagle sands. Currently we have one agreement with a party covering some of the areas of the leases and during 2008 we had two agreements expire under which exploration had begun on the leases. We also hold leases in southwestern North Dakota and have an agreement covering four Lodgepole prospects on those leases.

Liquidity and Capital Resources

Liquidity

The Company had no available cash, excluding certificate of deposits pledged for drilling permits, at June 30, 2009, and December 31, 2008. Our current liabilities exceed our current assets by $1,238,000 at June 30, 2009. We have suspended payments to our directors, general legal counsel, and employee since the second quarter of 2007 and have accrued $1,192,000 in expenses as of June 30, 2009. We expect to continue to suspend payments to these parties until sufficient funding can be secured to resume exploration operations and cover normal operating expenses. In April 2009, we received a loan of $20,800, which we used to pay lease payments due March 31, 2009 for $20,800. A private party made the loan to the Company in exchange for the right to be repaid once the Company acquires funding as well as a 0.5% royalty in the leases for which rentals were paid by the loan. We also received another loan in May 2009 from that individual in the amount of $27,398, under the same terms, which we used to pay some of the lease payments on June 1, 2009, covering the most prospective acres of leases upon which the rentals were due at that time. Those leases are located in our Starbuck Prospect area and the additional acreage which was located well to the west of the Starbuck Prospect were not able to be paid and expired. We have additional lease rental payments in the amount of $12,330 due by September 1, 2009. We may need to sell additional lease rights, obtain additional loans or secure funding to obtain the cash to make these payments, although there is no guarantee we will be able to sell additional lease rights or obtain loans or funding.

We are actively engaged in pursuing funding for our 2009 Drilling Program. The Program is an aggressive $9,500,000 exploration operation which would allow us to explore the potential of each of the areas we hold under lease. The Drilling Program covers exploration in three areas: a development Red River Formation prospect in Slope County, North Dakota, on approximately 400 acres we acquired; the drilling of three Lodgepole Formation prospects we have on our North Dakota Leases; and twelve step out wells from the Federal 1-19 well on the Starbuck East prospect in Montana. The Company is proceeding with the relatively inexpensive process of permitting wells in its main block of leases in Valley County, Montana, in order to accommodate the drilling of the expected wells. The 2009 Drilling Program is separate from the agreements described below.

As of June 30, 2009, we had no revenues, had recurring losses prior to 2005 and since 2005, and had an accumulated deficit during the development stage. Our current cash position is not adequate to fund existing operations or exploration and development of its oil and gas properties. These situations raise substantial doubt about our ability to continue as a going concern.

COASTAL CARIBBEAN OILS & MINERALS, LTD.

FORM 10-Q

PART I - FINANCIAL INFORMATION

June 30, 2009

ITEM 2

Management's Discussion and Analysis of Financial Condition and Results of Operations (Continued)

Capital Resources

In May 2008, we entered an agreement with Cobra. Under the agreement, Cobra paid Coastal $180,000 for the option to acquire a half interest in approximately 87,000 acres of Coastal’s Valley County Leases. The agreement allowed the Company to pay its Lease rentals that were due on June 1, 2008, and brought in a new party to explore on the Leases. Cobra has until May 2010 to exercise the option by spending $1,000,000 on behalf of the Company, drilling wells on the leases covered by the agreement. Those leases included approximately 62,000 acres of leases that were formally under an agreement with F-Cross Resources that expired in 2008 and more than 20,000 acres of other leases Coastal held in Valley County. No drilling has taken place yet under this agreement.

Two other agreements covering the leases expired during 2008. The first of the two agreements was a farm-out agreement with Western Standard, entered in August 2007. Upon execution of the agreement, Western Standard paid us $40,000. Subsequently, they paid an additional $384,000, $255,000 of which to covered the costs of drilling the first well to test a shallow natural gas prospect in Valley County, Montana and $129,000 was paid to cover associated lease rentals. Western Standard would have had an interest in the first well drilled as well as an option to purchase a 50% interest in the 42,000 acres under the lease. Upon receiving the funds to cover lease rentals, we repaid in full our loan of $126,000. Under the loan agreement, the individual that loaned us the money continues to hold a 5% overriding royalty on the same approximately 42,000 acres that are covered in the Western Standard agreement.

The first well under this agreement was drilled during October 2007, to test a shallow natural gas prospect near the middle of the Company’s Valley County Leases. The well, known as the Federal 1-19 Well, had three objectives: to confirm the 34,000 acre Starbuck East Prospect by finding that the Eagle formation was high to surrounding wells off the Prospect; to confirm that there were good natural gas shows in the Starbuck East Prospect; and to find commercial gas in either the Eagle formation or the Judith River formation. The first two objectives were met. Due to drilling damage, the third objective has not yet been met.

During October 2007, the Federal 1-19 well reached a total depth of 1,126 feet, and confirmed the structural high that was targeted. The well also had gas shows in two zones. Casing was run into the hole and operations to complete and test the well were scheduled to begin at the end of November, but were delayed by equipment repairs. The well is located on Federal land and the Bureau of Land Management would not allow the completion and testing operations or any further drilling to begin until July 2008, so operations were suspended until that time. The Company also received an additional $29,000 from Western Standard to cover additional drilling and other costs associated with the delay in well completion, which has been recorded as a reduction in capitalized petroleum lease costs. Western Standard paid the estimated well completion costs of $65,000 and operations to complete and test the well were performed in two stages during the third quarter and proceeded to the third stage in the fourth quarter of 2008. In October 2008, the Company received approximately $29,000 from Western Standard to pay for the third stage of operations which included stimulation of the well, a common procedure in completing oil and gas wells.

COASTAL CARIBBEAN OILS & MINERALS, LTD.

FORM 10-Q

PART I - FINANCIAL INFORMATION

June 30, 2009

ITEM 2

Management's Discussion and Analysis of Financial Condition and Results of Operations (Continued)

The Company was unable to determine by this well whether the target formations contain economic quantities of gas. Drilling damage in the well prevented the testing of either of the prospective formations at this location. Completion efforts found that the Eagle formation was damaged by the initial drilling and the formation was not able to be tested from this well. Further drilling into the Eagle formation during completion did not yield gas like the gas show seen from the upper part of the formation that was damaged. The Judith River formation, a secondary target, was damaged by drilling fluids lost into the formation while drilling through it to get to the Eagle formation, the primary target. Future wells to test this structure will incorporate the information obtained from these wells to prevent that damage from occurring again in other locations on the structure.

It is not unusual that the first well confirming a structure does not become a producing well. The test well did produce valuable information about the two gas bearing formations and their potential for economically feasible commercial gas production. Problems encountered in drilling the test well can now be avoided when future wells are drilled on the Starbuck East Prospect. With the first two objectives met, the Company will now focus on achieving the third objective, specifically finding commercial gas in either the Eagle or Judith River formations. We have received one permit to drill a step-out well and are currently in the permitting process for two more.

After the completion efforts on the Federal 1-19 well were finished, Western Standard had the option to purchase a 50% interest in approximately 42,000 acres near the well location for $1,000,000. The time to exercise that option passed and Western Standard did not exercise it, so we regained complete control of the leases formerly under the Western Standard agreement and Western Standard no longer has an interest in them. The Company will abandon the Federal 1-19 well in August 2009.

The other agreement that expired in 2008 was with F-Cross and was entered in September of 2007, covering approximately 64,000 acres on the northwest part of our Valley County Leases. Under the agreement, F-Cross had the option to drill a Lodgepole test well within six months and after drilling that well had the further option to acquire an interest in surrounding acreage. F-Cross was to pay for the cost of drilling the initial well and will receive a 100% working interest in the well until payout and an 80% working interest subsequent to payout. F-Cross exercised its option and the first Lodgepole test well was spudded on November 3, 2007. Drilling has finished, but the well is still awaiting completion and testing of several zones which have potential for both oil and gas. However, F-Cross did not meet the requirements in the agreement and in late March 2008 the option to acquire an interest in additional acreage expired, leaving F-Cross with rights only in the section in which it drilled.

COASTAL CARIBBEAN OILS & MINERALS, LTD.

FORM 10-Q

PART I - FINANCIAL INFORMATION

June 30, 2009

ITEM 2

Management's Discussion and Analysis of Financial Condition and Results of Operations (Continued)

In North Dakota, we control the working interest on approximately 8,510 net acres in Slope, Billings, and Stark Counties, on which a number of drillable prospects have been mapped to date. The depth of wells in North Dakota is greater than in Montana (approximately 9,500 feet versus approximately 5,000 feet), and thus the cost of drilling is higher. A typical North Dakota wildcat well costs about $1.5 million to drill. We had originally intended to bring in others to share the risk and investment in wells it drills in North Dakota until the Company is in a stronger financial position, but are now actively seeking funding to allow us to begin such exploration on our own.

In December of 2007 we entered a second farm-out agreement with Western Standard. Under the agreement, we assigned leases over four of our high-graded Lodgepole Reef prospects to Western Standard in return for $80,000 which we received between November 2007 and April 2008. We will also retain a back-in working interest of 20% in the leases after payout. The leases cover all rights below the Tyler formation, including the Lodgepole formation, with an 80% net revenue interest. We acquired these and other leases in the area in 2005 from Oil For America for $50,000 and we have invested some additional funds to geochemically test and high-grade these and other prospects on the leases. Oil For America has agreed to waive the drilling obligation on these four prospects. We will still retain three additional Lodgepole reef prospects on our North Dakota leases that are not covered by this farm-out agreement.

If our funding efforts are successful, we plan to drill or participate in as many as sixteen exploratory wells under our 2009 Drilling Plan. However, the number of wells that we drill in 2009 and their cost will be subject to various factors, including whether or not we can obtain sufficient funding to carry out the 2009 drilling program, whether Cobra will exercise its option and begin exploration under its agreements, the availability of drilling rigs that we can hire and whether we drill alone or with other participants. In addition, we could reduce the number of wells that we drill if oil and natural gas prices were to decline significantly. We expect the cost of drilling the sixteen wells to depend upon many factors, including those above, which may affect the cost of operations and whether and to what extent others participate with the Company.

Results of Operations

Six months ended June 30, 2009 vs. June 30, 2008

We did not conduct drilling activities in the first half of 2009 or 2008. Our efforts have been focused on soliciting funding or potential partners for our 2009 drilling program. Substantially all the drilling activity on our leases for 2008 was funded under farm-out agreements with other entities, and we expect that to continue in 2009. Therefore, except for $96,409 in legacy costs required to move forward with the Company’s 2009 Drilling Program, our expenses were primarily administrative and our 2009 administrative expenses remained consistent with 2008 amounts.

Our interest income decreased in 2009 from 2008 due to lower cash balances.

COASTAL CARIBBEAN OILS & MINERALS, LTD.

FORM 10-Q

PART I - FINANCIAL INFORMATION

June 30, 2009

ITEM 2

Management's Discussion and Analysis of Financial Condition and Results of Operations (Continued)

Three months ended June 30, 2009 vs. June 30, 2008

We did not conduct drilling activities in the second quarter of 2009 or 2008. Our efforts have been focused on soliciting funding or potential partners for our 2009 drilling program. Substantially all the drilling activity on our leases for 2008 was funded under farm-out agreements with other entities, and we expect that to continue in 2009. Therefore, except for $96,409 in legacy costs required to move forward with the Company’s 2009 Drilling Program, our expenses were primarily administrative and our 2009 administrative expenses remained consistent with 2008 amounts.

Our interest income decreased in 2009 from 2008 due to lower cash balances.

ITEM 3

Quantitative and Qualitative Disclosure About Market Risk

The Company does not have any significant exposure to market risk as there were no investments in marketable securities at June 30, 2009.

ITEM 4

Controls and Procedures

Management’s annual report on internal control over financial reporting.

We maintain controls and procedures designed to ensure that information required to be disclosed in the reports that the Company files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the Securities and Exchange Commission. Our Chief Executive Officer and our Chief Financial Officer, after evaluating the effectiveness of our “disclosure controls and procedures” (as defined in the Securities Exchange Act of 1934 (the “Exchange Act”) Rules 13a-15(e) or 15d-15(e)) as of the end of the period covered by this quarterly report, have concluded that our disclosure controls and procedures are effective based on their evaluation of these controls and procedures required by paragraph (b) of Exchange Act Rules 13a-15 or 15d-15.

Changes in internal controls. The Company made no changes in its internal control over financial reporting that occurred during the Company’s first fiscal quarter that has materially affected, or which is reasonably likely to materially affect the Company’s internal control over financial reporting.

Limitations on the Effectiveness of Controls Our management, including our Chief Executive and Chief Financial Officer, does not expect that our disclosure controls and internal controls will prevent all error and all fraud. A control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Because of the inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, within the Company have been detected. These inherent limitations include the realities that judgments in decision-making can be faulty, and that breakdowns can occur because of simple error or mistake. Additionally, controls can be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the control.

COASTAL CARIBBEAN OILS & MINERALS, LTD.

FORM 10-Q

PART I - FINANCIAL INFORMATION

June 30, 2009

The design of any system of controls also is based in part upon certain assumptions about the likelihood of future events, and there can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions; over time, controls may become inadequate because of changes in conditions, or the degree of compliance with the policies or procedures may deteriorate. Because of the inherent limitations in a cost-effective control system, misstatements due to error or fraud may occur and not be detected.

(This space intentionally left blank)

COASTAL CARIBBEAN OILS & MINERALS, LTD.

FORM 10-Q

PART II - OTHER INFORMATION

June 30, 2009

ITEM 5

Other Information

The Internal Revenue Code of 1986, as amended, provides special rules for distributions received by U.S. holders on stock of a passive foreign investment company (PFIC), as well as amounts received from the sale or other disposition of PFIC stock. Under the PFIC rules, a non-U.S. corporation will be classified as a PFIC for U.S. federal income tax purposes in any taxable year in which, after applying certain look-through rules, either (1) at least 75 percent of its gross income is passive income or (2) at least 50 percent of the gross value of its assets is attributable to assets that produce passive income or are held for the production of passive income.

The Company believes that it would not be classified as a PFIC for the year 2008, because it derived the majority of its gross income in 2008 from the sale of interests in parts of its leases to other companies through farm-out agreements, and received a relatively small amount of interest the Company. However, the Company may have been considered a PFIC in previous years, which could result in negative tax consequences to a shareholder. The determination of whether the Company will be considered a PFIC for United States federal income tax purposes is an annual determination that cannot be made until the close of the fiscal year. Also, how the Company was classified last year does not affect how it will be classified this year.

If, for any taxable year, the Company’s passive income or assets that produce passive income exceed levels provided by U.S. law, the Company would be a "passive foreign investment company," or PFIC, for U.S. federal income tax purposes. For the years 1987 through 2004 and in 2006, Coastal Caribbean's passive income and assets that produce passive income exceeded those levels and for those years Coastal Caribbean constituted a PFIC. If Coastal Caribbean is a PFIC for any taxable year, then the Company’s U.S. shareholders potentially would be subject to adverse U.S. tax consequences of holding and disposing of shares of our common stock for that year and for future tax years. Any gain from the sale of, and certain distributions with respect to, shares of the Company’s common stock, would cause a U.S. holder to become liable for U.S. federal income tax under section 1291 of the Internal Revenue Code (the interest charge regime). The tax is computed by allocating the amount of the gain on the sale or the amount of the distribution, as the case may be, to each day in the U.S. shareholder’s holding period. To the extent that the amount is allocated to a year, other than the year of the disposition or distribution, in which the corporation was treated as a PFIC with respect to the U.S. holder, the income will be taxed as ordinary income at the highest rate in effect for that year, plus an interest charge.

For further information, refer to the consolidated financial statements and footnotes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2008.

COASTAL CARIBBEAN OILS & MINERALS, LTD.

FORM 10-Q

PART II - OTHER INFORMATION

June 30, 2009

ITEM 6

Exhibits

31.1 Certification pursuant to Rule 13a-14 by Phillip W. Ware

32.1 Certification pursuant to Section 906 by Phillip W. Ware

COASTAL CARIBBEAN OILS & MINERALS, LTD.

FORM 10-Q

June 30, 2009

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.

	COASTAL CARIBBEAN OILS & MINERALS, LTD.
	Registrant


Date: August 24, 2009	By	/s/ Phillip W. Ware
		Phillip W. Ware
		Principal Executive Officer,
		President and Principal Financial Officer