bspe_10q.htm

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes x No o

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

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PART I FINANCIAL INFORMATION
Item 1.	Financial Statements
	Consolidated Balance Sheets as of January 31, 2014 and October 31, 2013 (unaudited)		3
	Consolidated Statements of Operations for the three months ended January 31, 2014 and 2013 (unaudited)		4
	Consolidated Statements of Cash Flows for the three months ended January 31, 2014 and 2013 (unaudited)		5
	Condensed Notes to Consolidated Financial Statements (unaudited)		6
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		9
Item 3.	Quantitative and Qualitative Disclosures About Market Risk		13
Item 4.	Controls and Procedures		14

PART II OTHER INFORMATION
Item 1.	Legal Proceedings		16
Item 1A.	Risk Factors		16
Item 2.	Unregistered Sales of Securities and Use of Proceeds		16
Item 3.	Defaults Upon Senior Securities		16
Item 4.	Mine Safety Disclosures		16
Item 5.	Other Information		16
Item 6.	Exhibits		17
SIGNATURES			18

	January 31, 2014			October 31, 2013
ASSETS
Current Assets:
Cash and cash equivalents	$	702,712		$	1,335,237
Accounts receivable		315,971			417,597
Prepaid expenses		27,539			--
Total Current Assets		1,046,222			1,752,834
Oil and gas property costs (successful efforts method of accounting)
Proved		2,032,019			2,077,872
Other assets		50,054			50,312
TOTAL ASSETS	$	3,128,295		$	3,881,018

LIABILITIES AND STOCKHOLDERS’ DEFICIENCY
Current Liabilities:
Note payable	$	3,280,000		$	280,000
Accounts payable		2,396,725			523,365
Accrued expenses		3,245,671			3,121,900
Total Current Liabilities		8,922,396			3,925,265
Notes Payable, net of discount of $1,004,404 and $1,329,581		1,595,596			4,270,419
Asset Retirement obligation		64,141			649,233
Total Liabilities		10,582,133			8,844,917
Stockholders’ Deficiency:
Preferred stock - $0.01 par value; 10,000,000 shares authorized:
Series A - $.001 par value, 310,000 shares authorized, nil shares issued and outstanding		--			--
Common stock - $0.001 par value; 100,000,000 shares authorized; 17,722,485 and 17,719,360 shares issued and outstanding at January 31, 2014 and October 31, 2013, respectively		17,723			17,720
Additional paid-in capital		23,741,212			23,726,191
Accumulated deficit		(31,212,773	)		(28,707,810	)
Total Stockholders’ Deficiency		(7,453,838	)		(4,963,899	)
TOTAL LIABILITIES AND STOCKHOLDERS’ DEFICIENCY	$	3,128,295		$	3,881,018

	Three months ended January 31,
	2014			2013
Revenue:
Oil and gas revenue	$	328,297		$	361,986

Expenses:
Selling, general and administrative		341,635			347,267
Depreciation and depletion		197,801			158,549
Accretion		8,444			14,674
Lease operating expenses		178,780			165,826
Impairment of oil and gas property interest		2,219,813			--

Total expenses		2,946,473			686,316
Loss from Operations		(2,618,176	)		(324,330	)

Other income and expense:
Interest expense		(508,457	)		(282,081	)
Gain on sale of oil and gas properties		621,670			--
Other income		--			27,763
Total Other Income (Expense)		113,213			(254,318	)

Loss before provision for income taxes		(2,504,963	)		(578,648	)
Provision for income taxes		--			--
Net Loss		(2,504,963	)		(578,648	)
Preferred stock dividends		--			50,000
Net loss attributable to common shareholders	$	(2,504,963	)	$	(628,648	)

Loss Per Share attributable to common shareholders
Basic and diluted	$	(0.14	)	$	(0.04	)
Weighted Average Shares Outstanding
Basic and diluted		17,719,530			16,386,613

	2014			2013
CASH FLOWS FROM OPERATING ACTIVITIES:
Netloss	$	(2,504,963	)	$	(578,648	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Impairment of oil and gas property costs		2,219,813			--
Equity compensation expense		15,024			90,980
Amortization of debt discount		325,177			105,284
Depreciation, depletion and accretion		206,245			173,223
Gain on sale of oil and gas properties		(621,670	)		--
Changes in operating assets and liabilities:
Accounts receivable		151,626			19,360
Prepaid expense and other current assets		(27,539	)		6,538
Accounts payable		316,234			217,956
Net cash flows from operating activities		79,947			34,693

CASH FLOWS FROM INVESTING ACTIVITIES:
Oil and gas property costs		(712,472	)		(22,726	)
Net cash flows from investing activities		(712,472	)		(22,726	)

CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from notes payable		--			--
Net cash flows from financing activities		--			--
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS		(632,525	)		11,967
CASH AND CASH EQUIVALENTS - Beginning of period		1,335,237			1,160,320
CASH AND CASH EQUIVALENTS - End of period	$	702,712		$	1,172,287

Supplemental Disclosures

Cash paid for interest	$	85,004		$	--
Cash paid for income taxes	$	--		$	--

Supplemental non-cash activities:
Oil and gas property costs in accounts payable	$	1,680,897		$	--

Blacksands Petroleum, Inc. (hereinafter referred to as the “Company”) was incorporated in the State of Nevada on October 12, 2004. Since August 2007, the Company has been engaged in the exploration, development, exploitation and production of oil and natural gas. The Company sells its oil and gas products primarily to domestic pipelines and refineries. Its operations are presently focused in the States of Texas and New Mexico.

The accompanying unaudited interim financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America and rules of the Securities and Exchange Commission (“SEC”), and should be read in conjunction with the audited financial statements and notes thereto contained in annual report on Form 10-K for the year ended October 31, 2013 filed with the SEC on February 14, 2013. In the opinion of management, all adjustments, consisting of normal recurring adjustments, necessary for a fair presentation of financial position and the results of operations for the interim periods presented have been reflected herein. The results of operations for interim periods are not necessarily indicative of the results to be expected for the full year. Notes to the consolidated financial statements which would substantially duplicate the disclosure contained in the audited financial statements as reported in the 2013 annual report on Form 10-K have been omitted.

The Company follows the successful efforts method of accounting for its oil and natural gas properties. Oil and gas properties are periodically assessed to determine whether they have been impaired. Any impairment in value of unproved properties is charged to exploration expense. The costs of unproved properties, which are determined to be productive, are transferred to prove oil and gas properties and amortized on an equivalent unit-of-production basis. Exploratory expenses, including geological and geophysical expenses and delay rentals for unevaluated oil and gas properties, are charged to expense as incurred. Exploratory drilling costs are initially capitalized as unproved property but charged to expense if and when the well is determined not to have found proved oil and gas reserves. In accordance with ASC No. 935, exploratory drilling costs are evaluated within a one-year period after the completion of drilling. For proved properties, we compare expected undiscounted future cash flows at a producing field level to the unamortized capitalized cost of the asset. If the future undiscounted cash flows, based on our estimate of future natural gas and crude oil prices, operating costs, anticipated production from proved reserves and other relevant date, are lower than the unamortized capitalized cost, the capitalized cost is reduced to fair value. Fair value is calculated by discounting the future cash flows at an appropriate risk-adjusted discount rate.

Going Concern

As shown in the accompanying consolidated financial statements, the Company has incurred an accumulated deficit of $31,212,773 through January 31, 2014. In addition, the Company had a working capital deficit of $7,876,174 and cash and cash equivalents of $702,712 at January 31, 2014. The Company drilled three new wells in November 2013. In order to complete the wells, the Company must raise additional capital and/or sell down its interest in these wells. However, the Company cannot assure that it will accomplish this task.

The current rate of cash usage raises substantial doubt about the Company’s ability to continue as a going concern, absent the raising of additional capital and/or additional significant revenues from new oil production. In an effort to mitigate this near-term concern the Company is seeking to obtain sufficient funds to complete the three new wells drilled in November 2013 and to fund working capital. The Company’s financial statements do not include any adjustments relating to the recoverability and classification of recorded assets, or the amounts and classification of liabilities that might be necessary in the event that the Company cannot continue in existence.

The ARO reflects the estimated present value of the amount of dismantlement, removal, site reclamation and similar activities associated with the Company’s oil and gas properties. Inherent in the fair value calculation of the ARO are numerous assumptions and judgments including the ultimate settlement amounts, inflation factors, credit adjusted discount rates, timing of settlement, and changes in the legal, regulatory, environmental and political environments. To the extent future revisions to these assumptions impact the fair value of the existing ARO liability, a corresponding adjustment is made to the oil and gas property balance.

The Company, as an owner or lessee and operator of oil and gas properties, is subject to various federal, state and local laws and regulations relating to discharge of materials into, and protection of, the environment. These laws and regulations may, among other things, impose liability on the lessee under an oil and gas lease for the cost of pollution clean-up resulting from operations and subject the lessee to liability for pollution damages. In some instances, the Company may be directed to suspend or cease operations in the affected area. The Company maintains insurance coverage, which it believes is customary in the industry, although the Company is not fully insured against all environmental risks. The Company is not aware of any environmental claims existing as of January 31, 2014, which have not been provided for, covered by insurance or otherwise have a material impact on its financial position or results of operations. There can be no assurance, however, that current regulatory requirements will not change, or past noncompliance with environmental laws will not be discovered on the Company’s properties.

During the three months ended January 31, 2014 and 2013, the Company recorded stock-based compensation of $15,024 and $90,980, respectively, as general and administrative expenses. At January 31, 2014, the weighted average remaining life of the stock options is 6.10 years. The unamortized amount of stock-based compensation at January 31, 2014 was $52,034. This cost is expected to be recognized over a weighted average period of 0.67 years.

In January 2014, the Company sold its interest in all of the wells the Cabeza Creek Field for all depths from the surface to 8,500 feet below the surface in exchange for $50,000 and the assumption of all future liabilities associated with the plugging and abandoning of all wells in the Cabeza Creek Field ($593,536).

	2014			2013

Oil and gas revenues	$	328,297		$	308,045

Expenses
Selling, general and administrative		341,635			347,267
Depreciation and depletion		197,801			123,979
Accretion		8,444			4,515
Lease operating expense		140,759			138,620
Impairment of oil and gas property interest		2,219,813			--

Total expenses		2,908,452			614,381

Loss from operations		(2,580,155	)		(306,336	)

Other income (expense)		(508,457	)		(254,318	)

Net income	$	(3,088,612	)	$	(560,654	)

This Management's Discussion and Analysis of Financial Condition and Results of Operations includes a number of forward-looking statements that reflect Management's current views with respect to future events and financial performance. You can identify these statements by forward-looking words such as “may” “will,” “expect,” “anticipate,” “believe,” “estimate” and “continue,” or similar words. Those statements include statements regarding the intent, belief or current expectations of us and members of its management team as well as the assumptions on which such statements are based. Prospective investors are cautioned that any such forward-looking statements are not guarantees of future performance and involve risk and uncertainties, and that actual results may differ materially from those contemplated by such forward-looking statements.

Readers are urged to carefully review and consider the various disclosures made by us in this report and in our other reports filed with the Securities and Exchange Commission. Important factors currently known to us could cause actual results to differ materially from those in forward-looking statements. We undertake no obligation to update or revise forward-looking statements to reflect changed assumptions, the occurrence of unanticipated events or changes in the future operating results over time. We believe that its assumptions are based upon reasonable data derived from and known about our business and operations and the business and operations of the Company. No assurances are made that actual results of operations or the results of our future activities will not differ materially from its assumptions. Factors that could cause differences include, but are not limited to, expected market demand for the Company’s services, fluctuations in pricing for materials, and competition.

We currently focus our oil and natural gas exploration, exploitation and development operations on projects located in Colorado, New Mexico and Texas. The higher potential impact projects (“Core Focus Areas”) are concentrated on (i) Spraberry, Wolfberry, Cline, Strawn and Mississippian formations in the Permian Basin (Midland Basin) in W. Texas, (ii) conventional reef structures in the Pedregosa Basin in S.W. New Mexico and (iii) conventional structure and stratigraphic formations and unconventional resource formations in Southern Colorado. We also have an interest in the Beech Creek Field in Hardin County Texas, which we anticipate will provide us with immediate cash flow and additional upside through recompletion potential and new drilling opportunities (“Non-core Properties”).

We began oil and gas operations in the United States on November 1, 2009, with the purchase of a producing conventional oil and gas field, located in the Gulf Coast region of Texas, from Pioneer Natural Resources. Additionally, we acquired interests in two properties located in the Gulf Coast region of Texas and one property in our Core Focus Area located in West Texas.

The Core Focus Areas provide us with the opportunity to grow reserves and cash flow by drilling and developing the properties. The Core Focus Areas we currently plan to concentrate on developing are in the AP Clark Field. We will need to raise additional capital in order to complete the three wells drilled in the AP Clark Field in November 2013, as well as any potential future wells to be drilled.

Revenues for the three months ended January 31, 2014 totaled $328,297 as compared to $361,986 for the three months ended January 31, 2013. The decrease totaling $33,689 resulted from the lack of production in the Cabeza Creek Field prior to being sold in late January 2014.

Selling, general and administrative expenses decreased $5,632 from $347,267 in the three months ended January 31, 2013 to $341,635 in the three months ended January 31, 2014. This decrease is primarily the result of a decrease of $75,956 in the stock based compensation recorded in the quarter ended January 31, 2014 as the result of the vesting of previously granted stock options, and partially offset by additional consulting fees of $32,349 and professional services of $27,391. There were no additional options granted during the quarter ended January 31, 2014.

Depreciation, depletion and accretion increased $33,022 from $173,223 in the three months ended January 31, 2013 as compared to $206,245 for the period ended January 31, 2014. The increase is primarily a result of the depletion expense for the costs related to the AP Clark Field.

Interest expense increased by $226,376 from $282,081 in the three months ended January 31, 2013 to $508,457 in the three months ended January 31, 2014. This increase is primarily related to a $219,893 increase in the amortization of the discount on the amounts due to KP Rahr and additional interest of $6,654 on the additional loan made by Silver Bullet in the last half of 2013.

The gain on the sale of oil and gas properties of $621,670 in the three months ended January 31, 2014, was the result of selling our rights in the Cabeza Creek Field. In January 2014, we sold our interest in all of the wells in the Cabeza Creek Field for all depths from the surface to 8,500 feet below the surface in exchange for $50,000 and the assumption of $593,536 in current liabilities and all future liabilities associated with the plugging and abandoning of all wells in the Cabeza Creek Field.

The Company had cash and cash equivalents of $702,712 as of January 31, 2014. The Company owes approximately $2.4 million in currently due accounts payable, a substantial portion of which were incurred in the drilling of three new, uncompleted wells in the AP Clark Field. As such, we currently do not have sufficient cash to complete the new wells or engage in any further drilling or exploration activities. In addition, our cash balances are not sufficient to satisfy our anticipated cash requirements for normal operations, or to meet our immediate accounts payable and other obligations regarding our indebtedness or capital expenditures for the foreseeable future.

The accompanying consolidated financial statements have been prepared on a going concern basis, which contemplates the realization of assets and the settlement of liabilities and commitments in the normal course of business. As reflected in the accompanying consolidated financial statements, as of January 31, 2014, we had $702,712 in cash and cash equivalents on hand, a working capital deficiency of approximately $7.9 million and an accumulated deficit of approximately $31.2 million.

We have incurred substantial losses since inception and we are not operating at cash flow breakeven. Our cash balance at January 31, 2014 is not sufficient to fully fund our business plan or to satisfy our cash requirements for normal operations, to meet our immediate accounts payable or other obligations regarding our indebtedness or our anticipated development activities over the next twelve months. In view of our capital requirements, current cash resources, nondiscretionary expenses, debt and near term accounts payable and accrued expenses obligations, we may explore all strategic alternatives to maintain our business as a going concern including, but not limited to, a sale of assets of our company, or one or more other transactions that may include a comprehensive financial reorganization of our company.

In order to continue operations and engage in development of our properties, we will be dependent on raising capital, debt or equity, from outside sources to pay for further expansion, exploration and development of our business, and to meet current obligations. Such capital may not be available to us when we need it on terms acceptable to us if at all, particularly in the current global economic conditions. The issuance of additional equity securities by us will result in a dilution to our current stockholders which could depress the trading price of our common stock. Obtaining debt financing will increase our liabilities and future cash commitments. If we are unable to obtain financing in the amounts and on terms deemed acceptable to us, we may be unable to continue our business and may be required to scale back, sell a portion of or cease our operations. The terms of securities we issue in future capital transactions may be more favorable to our new investors, and may include preferences, superior voting rights and the issuance of warrants or other derivative securities, and issuances of incentive awards under equity employee incentive plans, which may have a further dilutive effect.

We may incur substantial costs in pursuing future capital financing, including investment banking fees, legal fees, accounting fees, securities law compliance fees, and other costs. We may also be required to recognize non-cash expenses in connection with certain securities we may issue, such as convertible notes and warrants, which may adversely impact our financial condition. However, there is no assurance that we will be able to obtain sufficient funds on terms acceptable to us or at all. If adequate additional funding is not available, we may be forced to limit our activities.

If we are not able to obtain sufficient capital either from the sale of assets or external sources of capital to fund our immediate operating requirements, we may determine that it is in the Company’s best interests to seek relief through a pre-packaged, pre-negotiated or other type of filing under Chapter 11 of the U.S. Bankruptcy Code.

In the event we seek protection under Chapter 11 of the U.S. Bankruptcy Code, it may be necessary, in order to obtain the approval of our creditors and the Bankruptcy Court to a plan of reorganization for the Company, to eliminate and cancel all existing equity of the Company, including common stock, options, warrants and other securities that are linked to our equity, which will result in a loss of the entire investment of the holders of such securities, including our stockholders. Further, if we were unable to implement a plan of reorganization or if sufficient debtor-in-possession financing were not available, we could be forced to liquidate under Chapter 7 of the U.S. Bankruptcy Code, which would result in a loss of your entire investment.

Cash provided by operating activities in the period ended January 31, 2014 was $79,947, compared to $34,693 in the period ended January 31, 2013. The increase in cash provided by operating activities was primarily a result of a $2,219,813 increase in the impairment costs for oil and gas properties, a $219,893 increase in the amortization of debt discounts and a $132,266 increase in accounts receivable which was offset by a $1,926,315 increase in the net loss, a gain of $621,670 on the sale of the Cabeza Creek Field and a $75,956 decrease in equity compensation expense.

Net cash used in investing activities for the three months ended January 31, 2014 was $712,472 compared to $22,726 in the period ended January 31, 2013. The costs for both periods presented relate to our oil and gas acquisitions and development activity. The costs in the three months ended January 31, 2014 represent the costs paid to drill the three new, uncompleted wells in the AP Clark Field. There were no acquisitions of additional leaseholds incurred in either quarter.

Accounting for oil and gas exploratory activity is subject to special accounting rules unique to the oil and gas industry. The acquisition of geological and geophysical seismic information, prior to the discovery of proved reserves, is expensed as incurred, similar to accounting for research and development costs. However, leasehold acquisition costs and exploratory well costs are capitalized on the balance sheet pending determination of whether proved oil and gas reserves have been discovered on the prospect.

For individually significant leaseholds, management periodically assesses for impairment based on exploration and drilling efforts to date. For leasehold acquisition costs that individually are relatively small, management exercises judgment and determines a percentage probability that the prospect ultimately will fail to find proved oil and gas reserves and pools that leasehold information with others in the geographic area. For prospects in areas that have had limited, or no, previous exploratory drilling, the percentage probability of ultimate failure is normally judged to be quite high. This judgmental percentage is multiplied by the leasehold acquisition cost, and that product is divided by the contractual period of the leasehold to determine a periodic leasehold impairment charge that is reported in exploration expense.

This judgmental probability percentage is reassessed and adjusted throughout the contractual period of the leasehold based on favorable or unfavorable exploratory activity on the leasehold or on adjacent leaseholds, and leasehold impairment amortization expense is adjusted prospectively. Management periodically assesses individually significant leaseholds for impairment based on the results of exploration and drilling efforts and the outlook for project commercialization.

For exploratory wells, drilling costs are temporarily capitalized, or “suspended,” on the balance sheet, pending a determination of whether potentially economic oil and gas reserves have been discovered by the drilling effort to justify completion of the find as a producing well. If exploratory wells encounter potentially economic quantities of oil and gas, the well costs remain capitalized on the balance sheet as long as sufficient progress assessing the reserves and the economic and operating viability of the project is being made. The accounting notion of “sufficient progress” is a judgmental area, but the accounting rules do prohibit continued capitalization of suspended well costs on the mere chance that future market conditions will improve or new technologies will be found that would make the project’s development economically profitable. Often, the ability to move the project into the development phase and record proved reserves is dependent on obtaining permits and government or co-venturer approvals, the timing of which is ultimately beyond our control. Exploratory well costs remain suspended as long as we are actively pursuing such approvals and permits, and believe they will be obtained. Once all required approvals and permits have been obtained, the projects are moved into the development phase, and the oil and gas reserves are designated as proved reserves. Once a determination is made the well did not encounter potentially economic oil and gas quantities, the well costs are expensed as a dry hole and reported in exploration expense.

Management reviews suspended well balances quarterly, continuously monitors the results of the additional appraisal drilling and seismic work, and expenses the suspended well costs as a dry hole when it determines the potential field does not warrant further investment in the near term. Criteria utilized in making this determination include evaluation of the reservoir characteristics and hydrocarbon properties, expected development costs, ability to apply existing technology to produce the reserves, fiscal terms, regulations or contract negotiations, and our required return on investment.

Engineering estimates of the quantities of proved reserves are inherently imprecise and represent only approximate amounts because of the judgments involved in developing such information. Reserve estimates are based on geological and engineering assessments of in-place hydrocarbon volumes, the production plan, historical extraction recovery and processing yield factors, installed plant operating capacity and operating approval limits. The reliability of these estimates at any point in time depends on both the quality and quantity of the technical and economic data and the efficiency of extracting and processing the hydrocarbons.

Despite the inherent imprecision in these engineering estimates, accounting rules require disclosure of “proved” reserve estimates due to the importance of these estimates to better understand the perceived value and future cash flows of a company’s exploration and production operations. There are several authoritative guidelines regarding the engineering criteria that must be met before estimated reserves can be designated as “proved.” Our reservoir engineers have policies and procedures in place consistent with these authoritative guidelines.

Proved reserve estimates are adjusted annually and during the year if significant changes occur, and take into account recent production and subsurface information about each field. Also, as required by current authoritative guidelines, the estimated future date when a field will be permanently shut down for economic reasons is based on 12-month average prices and year-end costs. This estimated date when production will end affects the amount of estimated reserves. Therefore, as prices and cost levels change from year to year, the estimate of proved reserves also changes.

Our proved reserves include estimated quantities related to production sharing contracts, which are reported under the “economic interest” method and are subject to fluctuations in prices of crude oil, natural gas and natural gas liquids; recoverable operating expenses; and capital costs. The estimation of proved developed reserves also is important to the statement of operations because the proved developed reserve estimate for a field serves as the denominator in the unit-of-production calculation of depreciation, depletion and amortization of the capitalized costs for that asset.

Under various contracts, permits and regulations, we have material legal obligations to remove tangible equipment and plug wells at the end of operations at operational sites. The fair values of obligations for dismantling and removing these facilities are accrued at the installation of the asset based on estimated discounted costs. Estimating the future asset removal costs necessary for this accounting calculation is difficult. Most of these removal obligations are many years, or decades, in the future and the contracts and regulations often have vague descriptions of what removal practices and criteria must be met when the removal event actually occurs. Asset removal technologies and costs, regulatory and other compliance considerations, expenditure timing, and other inputs into valuation of the obligation, including discount and inflation rates, are also subject to change.

Our management, with the participation of our interim president and chief financial officer, evaluated the effectiveness of our disclosure controls and procedures pursuant to Rule 13a-15 under the Securities Exchange Act of 1934 as of January 31, 2014. In designing and evaluating the disclosure controls and procedures, management recognizes that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives. In addition, the design of disclosure controls and procedures must reflect the fact that there are resource constraints and that management is required to apply its judgment in evaluating the benefits of possible controls and procedures relative to their costs.

Based on management’s evaluation, our interim president and chief financial officer concluded that, as of January 31, 2014 our disclosure controls and procedures are not designed at a reasonable assurance level and are ineffective to provide reasonable assurance that information we are required to disclose in reports that we file or submit under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in SEC rules and forms, and that such information is accumulated and communicated to our management, including our chief executive officer and chief financial officer, as appropriate, to allow timely decisions regarding required disclosure. The material weaknesses, which relate to internal control over financial reporting, that were identified are:

Due to our small size, we did not have sufficient personnel in our accounting and financial reporting functions nor do we have a proper segregation of duties. During the period ended January 31, 2014, we had limited staff that performed nearly all aspects of our financial reporting process, including, but not limited to, access to the underlying accounting records and systems, the ability to post and record journal entries and responsibility for the preparation of the financial statements. This creates certain incompatible duties and a lack of review over the financial reporting process that would likely result in a failure to detect errors in spreadsheets, calculations, or assumptions used to compile the financial statements and related disclosures as filed with the Securities and Exchange Commission. In addition, we have had an overreliance on consultants involved in our financial statement closing process. As a result we were not able to achieve adequate segregation of duties and were not able to provide for adequate reviewing of the financial statements. This control deficiency, which is pervasive in nature, results in a reasonable possibility that material misstatements of the financial statements will not be prevented or detected on a timely basis; and

We are committed to improving our financial organization. When funds are available, we will look to increase our personnel resources and technical accounting expertise within the accounting function to resolve non-routine or complex accounting matters. As our operations are relatively small and we continue to have net cash losses each quarter, we do not anticipate being able to hire additional internal personnel until such time as our operations are profitable on a cash basis or until our operations are large enough to justify the hiring of additional accounting personnel. As necessary, we will engage consultants in the future in order to ensure proper accounting for our consolidated financial statements.

Management believes that hiring additional knowledgeable personnel with technical accounting expertise will remedy the following material weakness: insufficient personnel with an appropriate level of technical accounting knowledge, experience, and training in the application of GAAP commensurate with our complexity and our financial accounting and reporting requirements.

Management believes that the hiring of additional personnel who have the technical expertise and knowledge with the non-routine or technical issues we have encountered in the past will result in both proper recording of these transactions and a much more knowledgeable finance department as a whole. Due to the fact that our internal accounting staff consists of a Chief Financial Officer and a bookkeeper, additional personnel will also ensure the proper segregation of duties and provide more checks and balances within the department. Additional personnel will also provide the cross training needed to support us if personnel turn over issues within the department occur. We believe this will greatly increase our internal control procedures in the future.

Other than the resignation of Bruno Mosimann as our interim Chief Executive Officer and President, effective December 24, 2013 and the appointment of Rhonda Rosen as interim President, effective December 30, 2013, there were no changes in our internal control over financial reporting that occurred during the quarter ended January 31, 2014 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

31.01		Certification of Principal Executive Officer pursuant to Exchange Act Rules 13a-14(a) and 15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

31.02		Certification of Chief Financial Officer pursuant to Exchange Act Rules 13a-14(a) and 15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32.01		Certifications of Principal Executive Officer and Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

101.INS		XBRL Instance Document

101.SCH		XBRL Taxonomy Extension Schema Document

101.CAL		XBRL Taxonomy Calculation Linkbase Document

101.LAB		XBRL Taxonomy Label Linkbase Document

101.PRE		XBRL Taxonomy Presentation Linkbase Document

101.DEF		XBRL Taxonomy Extension Definition Linkbase Document

Nevada		20-1740044
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

Large accelerated filer	o	Accelerated filer	o
Non-accelerated filer	o	Smaller reporting company	x
(Do not check if a smaller reporting company)

Beginning balance at November 1	$	649,233
Liabilities settled		--
Liabilities incurred through acquisition of assets		--
Liabilities settled through sale of assets		(593,536	)
Accretion expense		8,444
Ending balance at January 31	$	64,141

	Number of Shares		Weighted Average Exercise Price
Outstanding at November 1, 2013		1,046,333	$	3.12
Granted		-		-
Exercised		-		-
Cancelled		-		-
Outstanding at January 31, 2014		1,046,333	$	3.12
Exercisable at January 31, 2014		1,002,333	$	3.07

	BLACKSANDS PETROLEUM, INC.

Date: March 12, 2014	By:	/s/ RHONDA ROSEN
		Name: Rhonda Rosen
		Title: Interim President (Principal Executive Officer)

Date: March 12, 2014	By:	/s/ DONALD GIANNATTASIO
		Name: Donald Giannattasio
		Title: Chief Financial Officer