Blacksands Petroleum (BSPE) 10-K 14 Feb 14 2013 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Oct. 31, 2013	Feb. 12, 2014	Apr. 30, 2013
Document And Entity Information	'	'	'
Entity Registrant Name	'BLACKSANDS PETROLEUM, INC.	'	'
Entity Central Index Key	'0001308137	'	'
Document Type	'10-K	'	'
Document Period End Date	31-Oct-13	'	'
Amendment Flag	'false	'	'
Current Fiscal Year End Date	'--10-31	'	'
Is Entity a Well-known Seasoned Issuer?	'No	'	'
Is Entity a Voluntary Filer?	'No	'	'
Is Entity's Reporting Status Current?	'Yes	'	'
Entity Filer Category	'Smaller Reporting Company	'	'
Entity Common Stock, Shares Outstanding	'	17,703,792	'
Entity Public Float	'	'	$43,279,556.20
Document Fiscal Period Focus	'FY	'	'
Document Fiscal Year Focus	'2013	'	'

Consolidated_Balance_Sheets_Un

Consolidated Balance Sheets (Unaudited) (USD $)	Oct. 31, 2013	Oct. 31, 2012
Current Assets:	'	'
Cash and cash equivalents	$1,335,237	'
Accounts receivable	417,597	402,162
Total Current Assets	1,752,834	1,562,482
Oil and gas property costs (successful efforts method of accounting)	'	'
Proved	2,077,872	5,284,597
Unproved	'	1,934,595
Other assets	50,312	220,984
TOTAL ASSETS	3,881,018	9,002,658
Current Liabilities:	'	'
Note payable	280,000	60,000
Accounts payable	523,365	158,131
Accrued expenses	3,121,900	2,416,857
Total Current Liabilities	3,925,265	2,634,988
Notes payable	4,270,419	3,591,866
Asset Retirement obligation	649,233	609,502
Total Liabilities	8,844,917	6,836,356
Stockholders' Equity:	'	'
Preferred stock - $0.001 par value; 10,000,000 shares authorized:	'	'
Series A - $.001 par value, 310,000 shares authorized, 0 and 250,000 shares issued and outstanding	'	250
Common stock - $0.001 par value; 100,000,000 shares authorized; 17,719,360 and 16,386,443 shares issued and outstanding at October 31, 2013 and October 31, 2012, respectively	17,720	16,387
Additional paid-in capital	23,726,191	22,463,501
Accumulated deficit	-28,707,810	-20,313,836
Total Stockholders' Equity	-4,963,899	2,166,302
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	$3,881,018	$9,002,658

Consolidated_Balance_Sheets_Un1

Consolidated Balance Sheets (Unaudited) (Parenthetical) (USD $)	Oct. 31, 2013	Oct. 31, 2012
Consolidated Balance Sheets Parenthetical	'	'
Preferred stock, par value	$0.00	$0.01
Preferred stock, authorized shares	10,000,000	10,000,000
Series A Preferred stock, par value	$0.00	$0.00
Series A Preferred stock, authorized shares	310,000	310,000
Series A Preferred stock, issued shares	0	250,000
Series A Preferred stock, outstanding shares	0	250,000
Common stock par value	$0.00	$0.00
Common stock shares authorized	100,000,000	100,000,000
Common stock shares issued	17,719,360	16,386,443
Common stock shares outstanding	17,719,360	16,386,443

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (Unaudited) (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012
Revenue:	'	'
Oil and gas revenue	$1,690,249	$1,588,728
Expenses:	'	'
Selling, general and administrative	1,443,223	1,842,463
Depreciation and depletion	969,511	657,472
Accretion	39,731	53,720
Lease operating expenses	765,643	769,769
Impairment of oil and gas property interest	4,820,770	225,543
Oil and gas exploration costs	699,335	952,320
Total expenses	8,738,213	4,501,287
Loss from Operations	-7,047,964	-2,912,559
Other income and expense:	'	'
Interest expense	-1,401,611	-449,881
Loss on sale of assets	'	10,277
Other income	55,601	54,000
Total Other Income (Expense)	-1,346,010	-385,604
Loss before provision for income taxes	-8,393,974	-3,298,163
Provision for income taxes	'	'
Net Loss	-8,393,974	-3,298,163
Preferred stock Dividends	-200,000	-200,000
Net loss attributable to common shareholders	-8,593,974	-3,498,163
Loss Per Share attributable to common shareholders Basic and diluted	($0.53)	($0.21)
Weighted Average Shares Outstanding Basic and diluted	$16,405,142	$16,382,660

Consolidated_Statement_of_Stoc

Consolidated Statement of Stockholders' Equity (USD $)	Preferred Stock	Common Stock	Additional Paid-In Capital	Retained Deficit	Total
Beginning Balance, Amount at Oct. 31, 2011	$250	$16,378	$21,949,403	($17,015,673)	$4,950,358
Beginning Balance, Shares at Oct. 31, 2011	250,000	16,377,068	'	'	'
Stock issued to director for services, Shares	'	9,375	'	'	88,000
Stock issued to director for services, Amount	'	9	64,679	'	64,688
Stock based compensation	'	'	449,419	'	449,419
Net loss	'	'	'	-3,298,163	-3,298,163
Ending Balance, Amount at Oct. 31, 2012	250	16,387	22,463,501	-20,313,836	2,166,302
Ending Balance, Shares at Oct. 31, 2012	250,000	16,386,443	'	'	'
Stock issued to director for services, Shares	'	6,250	'	'	'
Stock issued to director for services, Amount	'	6	24,787	'	24,793
Stock based compensation	'	'	238,980	'	238,980
Shares issued in private placement, Shares	'	500,000	'	'	'
Shares issued in private placement, Amount	'	500	999,500	'	1,000,000
Conversion of preferred shares, Shares	-250,000	826,667	'	'	'
Conversion of preferred shares, Amount	-250	827	-577	'	'
Net loss	'	'	'	-8,393,974	-8,393,974
Ending Balance, Amount at Oct. 31, 2013	'	$17,720	$23,726,191	($28,707,810)	($4,963,899)
Ending Balance, Shares at Oct. 31, 2013	'	17,719,360	'	'	'

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (Unaudited) (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012
CASH FLOWS FROM OPERATING ACTIVITIES:	'	'
Net loss	($8,393,974)	($3,298,163)
Adjustments to reconcile net loss to net cash used in operating activities:	'	'
Impairment of oil and gas property costs	4,820,770	225,543
Equity compensation expense	263,773	514,107
Depreciation, depletion and accretion	1,009,242	711,192
Amortization of debt discount	678,553	70,883
Gain on sale of assets	'	-10,277
Loss from dry hole	'	952,320
Changes in operating assets and liabilities:	'	'
Accounts receivable	-15,435	401,087
Prepaid expense and other current assets	169,611	-16,359
Accounts payable and accrued expenses	1,070,278	691,101
Net cash flows provided by (used in) operating activities	-397,182	241,434
CASH FLOWS FROM INVESTING ACTIVITIES	'	'
Cash paid for oil and gas properties	-647,901	-2,940,676
Cash received from the sale of oil and gas properties	'	22,500
Cash paid for purchase of fixed assets	'	-3,252
Net cash flows used in investing activities	-647,901	-2,921,428
CASH FLOWS FROM FINANCING ACTIVITIES:	'	'
Proceeds from notes payable	220,000	1,000,000
Proceeds from joint venture agreement	'	2,600,000
Proceeds from sale of common stock	1,000,000	'
Net cash flows from financing activities	1,220,000	3,600,000
NET INCREASE IN CASH AND CASH EQUIVALENTS	174,917	920,006
CASH AND CASH EQUIVALENTS - Beginning of period	1,160,320	240,314
CASH AND CASH EQUIVALENTS - End of period	1,335,237	1,160,320
Supplemental Disclosures	'	'
Cash paid for interest	223,599	'
Cash paid for income taxes	'	'
Supplemental non-cash activities	'	'
Discount on debt	'	2,079,017
Revision of asset retirement obligation	'	33,128
Asset retirement obligation transferred through sale of asset	'	154,664
Oil and gas exploration costs in accrued liabilities	'	952,320
Conversion of Preferred Stock to Common Stock	$827	'

The_Company_and_Summary_of_Sig

The Company and Summary of Significant Accounting Policies	12 Months Ended
	Oct. 31, 2013
Notes to Financial Statements	'
Note 1. The Company and Summary of Significant Accounting Policies	'
	Description of business and history
	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.
	Principles of consolidation
	The consolidated financial statements include the accounts of the Company and its wholly-owned subsidiaries, NRG Asset Management LLC, Copano Bay Holdings LLC, APClark LLC and BSPE Texas, LLC.All significant inter-company transactions and balances have been eliminated.
	Oil and Gas Properties
	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 proved 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 filed 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.
	During the years ended October 31, 2013 and 2012, the Company impaired its oil and gas properties by $4,820,770 and $225,543, which is reflected in the consolidated statement of operations (see Note 2).
	Asset Retirement Obligation
	The Company follows ASC 410—Asset Retirement and Environmental Obligations which requires entities to record the fair value of a liability for legal obligations associated with the retirement obligations of tangible long-lived assets in the period in which it is incurred. This standard requires the Company to record a liability for the fair value of the dismantlement and plugging and abandonment costs excluding salvage values. When the liability is initially recorded, the entity increases the carrying amount of the related long-lived asset. Over time, accretion of the liability is recognized each period and the capitalized cost is amortized over the useful life ofthe related asset. Upon settlement of the liability, an entity either settles the obligation for its recorded amount or incurs a gain or loss upon settlement.
	Accounting for Derivative Instruments
	ASC 815-24 (formerly SFAS No. 133, “Accounting for Derivative Instruments and Hedging Activities,”), requires all derivatives to be recorded on the balance sheet at fair value. The Company’s derivatives are separately valued and accounted for on the balance sheet. Fair values for securities traded in the open market and derivatives are based on quoted market prices. Where market prices are not readily available, fair values are determined using market based pricing models incorporating readily observable market data and requiring judgment and estimates.
	The pricing model the Company used for determining fair values of its derivatives is the Black-Scholes option-pricing model. Valuations derived from this model are subject to ongoing internal and external verification and review. The model uses market-sourced inputs such as interest rates, exchange rates and option volatilities. Selection of these inputs involves management’s judgment and may impact net income.
	Cash and cash equivalents and short term investments
	Cash and cash equivalents include cash on account and all highly liquid investments with original maturities of three months or less on the date of acquisition. Investments with original maturities of greater than three months but less than one year are considered short-term investments.
	Use of estimates
	The preparation of consolidated financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Actual results could differ from those estimates.
	The most critical estimate is the engineering estimate of proved oil and gas reserves. This estimate affects the application of the successful efforts method of accounting, the calculation of depreciation, depletion and amortization of the oil and gas properties and the estimate of the impairment of the oil and gas properties. It also affects the estimated lives used to determine asset retirement obligations. In addition, the estimates of proved oil and gas reserves are the basis for the related standardized measure of discounted future cash flows.
	Concentration of credit risks
	The Company’s consolidated financial assets that are exposed to credit risk consist primarily of cash and cash equivalents and accounts receivable. The Company maintained substantially all of its cash balances in a limited number of financial institutions. The balances are insured by the Federal Deposit Insurance Corporation up to $250,000. The Company had $749,965 in excess of this limit at October 31, 2013.
	Property and equipment
	Property and equipment are stated at cost less accumulated depreciation. Depreciation is provided principally on the straight-line method over the estimated useful lives of the assets, which are generally 3 to 27 years. The amounts of depreciation provided are sufficient to charge the cost of the related assets to operations over their estimated useful lives. Upon sale or other disposition of a depreciable property, cost and accumulated depreciation are removed from the accounts and any gain or loss is reflected in the statement of operations.
	The Company periodically evaluates whether events and circumstances have occurred that may warrant revision of the estimated useful life of fixed assets or whether the remaining balance of fixed assets should be evaluated for possible impairment. The Company uses an estimate of the related undiscounted cash flows over the remaining life of the fixed assets in measuring their recoverability.
	Revenue recognition
	Revenue is recognized when title to the products transfer to the purchaser. The Company uses the “sales method” to account for production revenue, whereby revenue is recognized on all oil, natural gas or other related products sold to our purchasers, regardless of whether the sales are proportionate to our ownership in the property. A receivable or liability is recognized only to the extent that there is an imbalance on a specific property greater than the expected remaining proved reserves. As of October 31, 2013, our aggregate production imbalances were not material.
	Stock-based compensation
	The Company follows the provisions of FASB ASC 718—Stock Compensation. The statement requires all stock-based payments to employees, including grants of employee stock options, to be recognized in the financial statements based on their fair values on the date of grant.
	Income taxes
	The Company accounts for its income taxes in accordance with ASC 740 Income Taxes, which requires recognition of deferred tax assets and liabilities for future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and tax credit carry forwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in operations in the period that includes the enactment date.A valuation allowance is provided for the amount of deferred tax assets that would otherwise be recorded for income tax benefits primarily relating to operating loss carryforwards as realization cannot be determined to be more likely than not.
	The statement establishes a more-likely-than-not threshold for recognizing the benefits of tax return positions in the financial statements. Also, the statement implements a process for measuring those tax positions which meet the recognition threshold of being ultimately sustained upon examination by the taxing authorities. There are no uncertain tax positions taken by the Company on its tax returns and the adoption of the statement had no material impact to the Company’s consolidated financial statements. The Company files tax returns in the US and states in which it has operations and is subject to taxation. Tax years subsequent to 2009 remain open to examination by U.S. federal and state tax jurisdictions.
	Net loss per common share
	The Company computes net income or loss per share in accordance with ASC 260 Earnings Per Share. Under the provisions of the Earnings per Share Topic ASC, basic net loss per share is computed by dividing the net loss available to common stockholders for the period by the weighted average number of shares of common stock outstanding during the period. The calculation of diluted net loss per share gives effect to common stock equivalents; however, potential common shares are excluded if their effect is anti-dilutive. The weighted average number of potentially dilutive common shares excluded from the calculation of diluted net income (loss) per share totaled 3,103,601 and 3,511,934 for the years ended October 31, 2013 and 2012, respectively.
	Fair Value of Financial Instruments
	The carrying amounts of financial instruments, including cash and cash equivalents, short-term investments, accounts receivable, accounts payable and accrued liabilities approximate fair value at October 31, 2013 and October 31, 2012 because of the short period to maturity of these instruments.
	Going Concern
	As shown in the accompanying consolidated financial statements, the Company has incurred an accumulated deficit of $28,707,810 through October 31, 2013. In addition, the Company had a working capital deficit of $2,172,431 and cash and cash equivalents of $1,335,237 at October 31, 2013. A substantial portion of the cash available at October 31, 2013 was used toward the drilling costs for the three new wells drilled 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 on 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.
	Reclassification
	During the quarter ended January 31, 2013, the Company discovered and corrected an error regarding its reporting for certain unvested option costs for a former employee. The error resulted in an overstatement of its general and administrative expenses and net losses and an overstatement of its additional paid in capital during the year ended October 31, 2012 by $145,482. In addition, the change reduced the net loss per share by $.01.

Oil_and_Gas_Property_Costs

Oil and Gas Property Costs	12 Months Ended
	Oct. 31, 2013
Notes to Financial Statements	'
Note 2. Oil and Gas Property Costs	'
	In the years ended October 31, 2013 and October 31, 2012, the Company incurred property acquisition costs as follows:
	Proved Properties
		2013			2012
	Balance, beginning of year	$	5,284,597		$	5,360,478
	Costs incurred during the year		647,901			862,407
	Asset retirement obligation acquired		--			33,128
	Depletion		(968,451	)		-656,411
	Impairment of oil and gas property costs		(2,886,175	)		(147,370	)
	Cost of property sold		--			(167,635	)
	Balance, end of year	$	2,077,872		$	5,284,597
	Unproved Properties
		2013			2012
	Balance, beginning of year	$	1,934,595		$	2,012,768
	Costs incurred during the year		--			--
	Impairment of oil and gas property costs		(1,934,595	)		(78,173	)
	Balance, end of year	$	--		$	1,934,595
	Blacksands Projects
	Proved Properties
	J.E. Pettus Gas Unit (known as “Cabeza Creek Field”) Acquisition in November 2009
	On November 9, 2009, the Company purchased the J.E. Pettus Gas Unit located in Goliad County, Texas for $402,569. The Company also incurred approximately $25,000 in fees associated with the acquisition, which were expensed when incurred. The Gas Unit includes four (4) active gas wells, (1) active oil well and 22 non-producing wells located on 3,689 acres in Goliad County, Texas. The leasehold working interest acquired by BSPE Texas is 100% leasehold working interest (80% net revenue interest) from the surface to 8,500 feet below the surface and 10.67% leasehold working interest (8.536% net revenue interest) below 8,500 feet.
	At October 31, 2013 and 2012, the Company compared the expected undiscounted future cash flows on a field by field basis to the unamortized capitalized cost of the asset. The Company determined that based on its analysis, capitalized costs for the field exceeded its fair value. As a result the Company recorded an impairment totaling $4,359 and $147,370, respectively.
	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.
	Beech Creek Oil Wells (known as “Beech Creek Field”) Acquisition in April 2010
	On April 5, 2010, the Company purchased different leasehold working interests in the Beech Creek Wells No. 1 and No A-2 located in Hardin County, Texas for $740,798 in cash. These property interests were previously owned by a group of five different working interest owners. A 30.0587% working interest (21.942851% net revenue interest) was acquired in the Beech Creek #1 well. A 24.4337% (18.3253% Net Revenue Interest) working interest was acquired in the Beech Creek A-2 well. Both of these wells are currently producing.
	AP Clark Wells (known as “Jo-Mill Field”) Acquisition in August 2010
	On August 10, 2010 the Company purchased aninterest in two operating wells and its leasehold interest in 1,257 acres for $460,000. As a result of the acquisition, the Company has a 25% gross working interest (18.75% net revenue interest) in the two operating wells. The Company also has an 18.875% gross working interest (14.15625% net revenue interest) on the leasehold interests acquired on the 1,257 acres. In addition, the Company agreed to carry Bonanza for a 2.5% gross leasehold working interest (1.875% net revenue interest) for the next well drilled on the property to the sales point.
	On November 29, 2010, the Company acquired the leasehold interests and rights in the AP Clark II Prospect from Westerly for $260,000 (ii) the Company paid Westerly $119,000 as advance payment towards 70% of the actual third party costs that will be required to receive an extension of certain leasehold properties included in the AP Clark II Prospect (as defined in the LAPA) (the “Extension Monies”) and (iii) the Company and Westerly agreed to drill the W.D. Everett Well No. 3 located within the AP Clark II Prospect (as defined in the LAPA) whereby all costs of such drilling operation shall be borne 30% by Westerly and 70% by the Company.
	The Company incurred $1,342,539 in drilling costs related to the drilling and completion of the W.D. Everett Well No. 3. In addition, during the quarter ended October 31, 2011, the Company drilled the Beaver Valley Ranch 6-1 well. Westerly elected to not participate for its full working interest in this well and has a working interest on this well of 15%. The Company was able to arrange for two unrelated parties to participate for an additional 20%. As a result, the Company has a working interest in this well of 65%. The Company incurred costs relating to the well totaling $1,166,225.These wells are currently Company operated.
	During the fiscal year 2012, the Company drilled two wells, the Livestock 7-1 and Livestock 18-1 for a total cost of $1,223,535 and $1,275,699, respectively.Westerly elected to not participate for its full working interest in these wells and has a working interest of 11.4% and 8.55%, respectively. The Company was able to arrange for four unrelated parties to participate in each of these wells for an additional 26%. As a result, the Company has a working interest in these well of 62.8% and 65.65%. These wells began production in November 2012. These wells are currently Company operated.
	During November 2013, the Company drilled three additional wells. These wells have not been completed to date.
	At October 31, 2013, the Company compared the expected undiscounted future cash flows on a field by field basis to the unamortized capitalized cost of the asset. The Company determined that based on its analysis, capitalized costs for the field exceeded its fair value. As a result the Company recorded an impairment totaling $2,881,816.
	Copano Bay
	Effective November 1, 2010, a newly organized subsidiary of the Company acquired a 50% working interest (37.5% net revenue interest) in certain operating oil and gas leases in and around Aransas County, Texas for $100,000. There are currently four active wells on the property. NRG Assets Management LLC, a Texas LLC and Texas registered operating company owned by the Company is the operator at all depths. In connection with the acquisition, the Company recorded an asset retirement obligation totaling $126,040. Effective July 1, 2012, the Company disposed of its interest in the property in exchange for $25,000. The Company reported a gain of $10,277 on the sale of this field.
	The following is a summary of the proforma information assuming the sale of the Copano Bay field had occurred as of the beginning of each fiscal year presented:
		2013			2012
	Oil and gas revenues	$	1,690,249		$	1,343,951
	Expenses
	Selling, general and administrative		1,443,223			1,829,078
	Depreciation and depletion		969,511			644,110
	Accretion		39,731			38,136
	Lease operating expense		765,643			581,344
	Impairment of oil and gas properties		4,820,770			225,543
	Oil and gas exploration costs		699,335			952,320
	Total expenses		8,738,213			4,270,531
	Loss from operations		(7,047,964	)		(2,926,580	)
	Other income (expense)		(1,346,010	)		(449,881	)
	Net income	$	(8,393,974	)	$	(3,376,461	)
	Unproved Properties
	Pedregosa Basin Field Acquisition in June 2010
	On June 18, 2010, the Company acquired a 50% undivided leasehold working interest (with an associated 40% net revenue interest) in and to approximately 147,262 acres of land, located in the Pedregosa Basin (SW New Mexico) for an initial acquisition cost of $1.5 million (the “Exploration Agreement”). Pursuant to the agreement, $1 million was paid at purchase and the remaining $500 thousand was due and subsequently paid on November 1, 2010. This remaining $500 thousand was reflected in the financial statements at October 31, 2010 as accounts payable. The property has no production and was accounted for as an acquisition of unproved property. In addition, the Companywasresponsible for acquiring 37 linear miles of 2-D seismic data. As a result of this acquisition, the Company recorded $1.5 million in unproved properties. Pursuant to an agreement, the Company is obligated to carry the drilling costs for a test well up to $1.2 million. Costs in excess of $1.2 million are to be split based upon the parties working interest. During the quarter ended April 30, 2011, the Company began drilling on a test well. The Company incurred $1,665,142 in capitalized exploration costs. During the quarter ended October 31, 2011, the Company determined that there were not economically feasible hydrocarbons at the test well site and expensed the costs of the well as exploration costs. During 2012, the Company determined that it owed an additional $952,320 for the drilling of this test well based on cost over runs reported to the Company by the operator of the well. During 2013, the Company was informed that an additional $171,790 was due on the drilling of the test well. This amount is reported in the statement of operations as exploration costs. The current leases are being held by production. As a result of the Company’s focus on developing the AP Clark Field, we will not have sufficient capital for the development of the Pedregosa Field. Accordingly, an impairment charge totaling $1,781,214 has been recorded during the year ended October 31, 2013.
	Del Norte Acquisition in September 2010
	On September 9, 2010, the Company acquired a 50% undivided leasehold working interest in and to approximately 3,200 acres of land located in Rio Grande County in Colorado from Dan A. Hughes Company for an initial acquisition cost of $200,000. The property has no production and was accounted for as an acquisition of unproved property. Pursuant to the agreement, the Company has the option to participate in the drilling of a test well. If the Company participates in the drilling of this test well, all costs associated with the well will be borne equally. As a result of this acquisition, the Company recorded $200,000 in unproved properties. In August 2011, leases covering approximately 1,240 of these acres expired. As a result, the Company reported an impairment charge of $77,703 for the year ended October 31, 2012 for the expired leases. As a result of the Company’s focus on developing the AP Clark Field, we will not have sufficient capital for the development of the Del Norte prospect. Accordingly, an impairment charge totaling $153,381 has been recorded during the year ended October 31, 2013.
	Cometa Ranch
	In September 2010, the Company acquired an undivided interest leased in approximately 1102 acres of land for approximately $78,000. As a result of the Company being unable to resolve title and ownership issues on this property, it has been determined the Company will not be able to develop this property. As such, a full impairment on the property was reported during the year ended October 31, 2012.

Debt

Debt	12 Months Ended
	Oct. 31, 2013
Notes to Financial Statements	'
Note 3. Debt	'
	The following is a summary of the debt outstanding at October 31,
		2013			2012
	Silver Bullet Properties	$	3,220,000		$	3,000,000
	PIE Energy		60,000			60,000
	KP-RAHR Ventures III, LLC, net
	of discount of $1,329,581 and $2,008,134		1,270,419			591,866
	Total		4,550,419			3,651,866
	Less current maturities		280,000			60,000
	Long-term debt	$	4,270,419		$	3,591,866
	On June 18, 2010, the Company entered into a bridge loan agreement (the “Bridge Loan Agreement”) with Talras Overseas S.A. (“Talras”). On such date, Talras made a bridge loan to the Company in the amount of $1,000,000 (the “Bridge Loan”). Under the Bridge Loan Agreement, the principal face amount of $1,000,000 was provided in the first tranche and subsequent tranches of $500,000 or more were permitted up to $2,500,000 in the aggregate to be funded by June 30, 2010. The Company had borrowed the total amount under the agreement of $2,500,000. This Bridge Loan was unsecured.
	The Bridge Loan bears interest at a rate of 6.0% per annum which amount shall, at the option of the Company, be payable either (i) in cash or (ii) by adding such interest to the accreted principal amount which is the outstanding principal amount including all PIK amounts (the “Accreted Principal Amount”).
	Under the original terms, the Company must pay the principal together with all interest accrued and unpaid at the earliest of (i) June 30, 2011 or (ii) the closing date of an investment or series of related investments in equity securities of the Company in an aggregate amount of at least $10 million including the Accreted Principal Amount and interest outstanding under the Bridge Loan Agreement and any other bridge loan agreements. Should an aggregate $10 million investment or series of related investments in equity securities of the Company occur prior to June 30, 2011, then all of the obligations due under this note will be converted automatically into equity shares of the Company. The Company evaluated the conversion feature under ASC 815 and determined that is was not a derivative.
	On October 29, 2010, the Company and Talrus entered into an exchange agreement, whereby the amount then outstanding on the Bridge Loan Agreement were exchanged for 250,000 shares of the Company’s Series A convertible preferred stock and warrants to purchase 333,333 shares of the Company’s common stock. The convertible preferred shares provide for dividends at the rate of 8% per annum of the stated value of the shares. The dividends are cumulative and payable in cash or in additional Series A Convertible Preferred shares. The shares are convertible at any time at the option of the holder into common stock at a conversion price of $3.75 per common share. If not previously converted, all outstanding shares of the Series A preferred stock, including any unpaid dividends, convert to shares of common stock on October 29, 2013. The warrants are exercisable at an exercise price of $6 per share through October 29, 2013. The preferred shares and accumulated dividends were converted into 826,667 shares of common stock on October 29, 2013. The warrants expired unexercised.
	Silver Bullet Properties
	On November 19, 2010, the Company entered into a loan agreement with Silver Bullet Property Holdings for a promissory note totaling $1,500,000. The note bears interest at the rate of 10% per annum and is due on the earlier of the date the Company closes on an offering with gross proceeds of at least $5 million or November 19, 2011. On September 27, 2011, the Company entered into an amendment to the promissory note dated November 19, 2010 (the “Note”) issued by the Company to Silver Bullet Property Holdings SDN BHD (the “Investor”). Pursuant to the amendment, the maturity date of the Note was amended from November 19, 2011 to February 1, 2013. In addition, the Investor loaned the Company an additional $1 million, with $500,000 loaned prior to October 31, 2011 and the remaining $500,000 received in two installments in November and December 2011. Pursuant to a security agreement, dated September 27, 2011, as security for the repayment of the Note, the Company granted the Investor a first priority lien on the Company’s oil and gas mineral leases in the ApClark Field. In April 2012, the parties agreed to further extend the note to May 1, 2014 and the investor agreed to an additional loan of $500,000 to the Company. The Company also granted a net proceeds interest (9% but reduced to 4.5% if the note is repaid prior to May 1, 2013) in the AP Clark properties included in the security agreement. The net proceeds interest represents the amount remaining from the proceeds of the sale of the property after deducting the related costs. The amendment was reviewed to determine its accounting treatment as a restructuring, extinguishment or modification and determined to be a modification. The Company received the additional $500,000 in June 2012. In September 2013, the parties agreed to further extend the Note to November 1, 2014.
	On August 29, 2013, the Company entered into an additional loan agreement with the Investor for a promissory note totaling $220,000 (the “Second Note”). The Second Note bears interest at the rate of 12% and is due on August 29, 2014.
	PIE Energy
	In November 2009, the Company received an interest-free advance from an unrelated third party totaling $60,000. In January 2011, the interest-free advances were converted into a note payable, which is due on January 11, 2012 and has a stated annual interest rate of 6%. In January 2012, the parties amended the agreement to extend the due date to January 11, 2013. All other terms and conditions remained unchanged. The note has not been extended further nor has the Company received a notice of default.
	Joint Venture Agreement
	On July 20, 2012, Blacksands Petroleum, Inc. (the “Company”) entered into a Contribution Agreement (the “Contribution Agreement”), between APClark, LLC, a wholly-owned subsidiary of the Company (“APClark”) and KP-RAHR Ventures III, LLC (“KP Ventures”). Pursuant to the Contribution Agreement (i) the Company contributed $1,000 and certain of the Company’s oil and gas assets to APClark in exchange for 1,000 shares of Class A Membership Units of ApClark (the “Class A Membership Units”) and (ii) KP Ventures contributed approximately $2,600,000 (the “KP Ventures Cash Consideration”) to APClark in consideration of 1,000 shares of Class B Non-Voting Convertible Preferred Membership Units of APClark (the “Class B Membership Units” and the transaction, the “Asset Transaction”). KP Ventures has the option to contribute additional funds to APClark, up to an aggregate of $7,600,000, for no further equity consideration.
	In connection with the Contribution Agreement, the Company entered into a Company Agreement (the “Operating Agreement”) governing the operations of APClark and defining various rights of the Company and KP Ventures.
	Pursuant to the Operating Agreement, KP Ventures shall receive a preferred return of 12% per annum (the “Preferred Return”) on the unrecovered KP Ventures Cash Consideration until such time as the KP Ventures Cash Consideration is repaid. In addition, KP Ventures receives a 1% overriding royalty from the production of the APClark oil and gas properties. Once the KP Ventures Cash Consideration is repaid, including all accrued Preferred Returns, the Class B Membership Units shall automatically convert into Class C Non-Voting Net Profit Membership Units (the “Class C Membership Units”), which represent a non-dilutable “Net Profits” interest (“NPI”) in APClark and the assets owned by APClark and a percentage of all outstanding membership units of APClark initially equal to the NPI. The amount of the NPI granted depends on when the KP Ventures Cash Consideration and Preferred Return is paid, as follows:
	Date of Repayment in Full	NPI %
	On or prior to six month anniversary		7.5	%
	After six months but on or prior to two year anniversary		15	%
	After two years but on or prior to three year anniversary		20	%
	After three years		50	%
	The Company will be responsible for the operations of APClark and has the right to appoint the sole director of APClark, The consent of KP Ventures is required in certain situations, including, but not limited to: expanding the scope of the business; admitting additional members or transfer of membership units; approve annual budget; any merger or sale of all or substantially all of the assets of APClark; voluntary liquidation, dissolution or winding up of APClark; and to make any cash distributions.
	In addition, the Company entered into a Pledge Agreement (the “Pledge Agreement”) pursuant to which it pledged the Class A Membership Units to KP Ventures to secure the Company’s obligations and performance thereunder and under the Contribution Agreement and Operating Agreement, which such Class A Membership Units shall be held pursuant to an escrow agreement.
	Previously, the Company entered into a security agreement, dated as of September 27, 2011, pursuant to which, as security for the repayment of promissory notes in the principal face amount of $3,000,000 (the “Notes”), issued to Silver Bullet Property Holdings SDN BHD (“Silver Bullet”) a first priority security interest (the “Security Interest”) in certain of the assets of the Company that were contributed to APClark pursuant to the Contribution Agreement (the “Pledged Assets”). In connection with the Asset Transaction, the Company, APClark, Silver Bullet and KP Ventures entered into a subordination agreement (the “Subordination Agreement”), pursuant to which Silver Bullet subordinated its Security Interest to KP Ventures, so that KP Ventures would have a first priority interest in the Pledged Assets until KP Ventures is repaid the KP Ventures Cash Consideration and Preferred Return. In addition, the Company previously granted Silver Bullet a “net proceeds” interest of 9% on the Pledged Assets (the “Silver Bullet NPI”), which Silver Bullet NPI was capped at 25% of the outstanding principal and accrued interest owed under the Notes (the “Silver Bullet NPI Limitation”).
	As consideration for Silver Bullet to enter into the Subordination Agreement, the Company agreed to increase the interest on the Notes to 12% per annum and remove the Silver Bullet NPI Limitation so there is no cap on the maximum amount of Silver Bullet NPI that Silver Bullet can receive.
	As a result of the required repayment of the equity to KP Ventures, the amount of the contribution has been reflected as a liability on the balance sheet. The Company has also recorded a discount on this liability relating to the relative fair value of the overriding royalties totaling $163,786 and net profits interest totaling $1,915,231. These discounts reduced the carrying value of the proved oil and gas costs. The carrying value of the discounts totaled $1,329,581 at October 31, 2013. The Company amortized $678,553 and $70,883 as additional interest expense in the fiscal years ended October 31, 2013 and 2012, respectively.

Asset_Retirement_Obligation

Asset Retirement Obligation	12 Months Ended
	Oct. 31, 2013
Notes to Financial Statements	'
Note 4. Asset Retirement Obligation	'
	The following table summarizes the change in the asset retirement obligation (“ARO”) for the years ended October 31,
		2013		2012
	Beginning balance at November 1	$	609,502	$	677,318
	Liabilities settled		--		--
	Liabilities incurred through acquisition of assets		--		--
	Liabilities transferred through sale of assets		--		(154,664	)
	Change in estimate of well life		--		33,128
	Accretion expense		39,731		53,720
	Ending balance at October 31	$	649,233	$	609,502
	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.

Stockholders_Equity

Stockholders' Equity	12 Months Ended
	Oct. 31, 2013
Notes to Financial Statements	'
Note 5. Stockholders' Equity	'
	Preferred Stock
	The Company is authorized to issue 10,000,000 shares of preferred stock at a par value of $.001.
	In October 2010, the Board of Directors designated 310,000 shares of the Company’s preferred stock as Series A Convertible Preferred Stock (“Series A Preferred”). The Series A Preferred are convertible into shares of common stock at a conversion price of $3.75. The shares are entitled to dividends at a rate of 8% of the stated value per share per annum. The dividends are payable annually on December 31 in cash or additional shares of the Series A Preferred, at the option of the Company. The Series A Preferred and any accrued and unpaid dividends will mandatorily convert into common shares on October 29, 2013. The outstanding Series A Preferred and accumulated unpaid dividends were converted into 826,667 shares of the Company’s common stock on October 29, 2013.
	Issuance of Common Stock
	In October 2013, the Company issued 500,000 shares of its common stock to Silver Bullet in exchange for $1,000,000. The base price paid by Silver Bullet will be reduced and additional shares issued if there is an issuance of securities or repricing of an existing right to a price less than the base share price paid by Silver Bullet within one year from the original issuance.
	Stock Options
	As of June 26, 2006, the Company’s Board of Directors approved, and a majority of the Company’s stockholders ratified, the adoption of the Company’s 2006 Stock Option Plan (the “Plan”), pursuant to which the Board of Directors has the ability to provide incentives through the issuance of options, stock, restricted stock, and other stock-based awards, representing up to 2,000,000 shares of the Company’s common stock, to certain employees, outside directors, officers, consultants and advisors. The 2006 Stock Option Plan allows the term of options granted to be determined by the Board of Directors not to exceed ten years. The Board of Directors is authorized to determine the vesting requirements of the options granted.
	During the Fiscal year ended October 31, 2012, stock options were granted to a director of the Company for options representing 88,000 common shares. The exercise price of the option is $4.50, with a ten year term, vesting equally over four years. The fair value of the option grants were estimated on the date of the grant using the Black-Scholes option-pricing model with the following weighted average assumptions: expected volatility of 134%, risk free interest rate of 0.77%; and expected lives of 3.7 years. During the years ended October, 31, 2013 and 2012, the Company recorded stock based compensation totaling $238,980 and $449,419 as a result of the stock option grants.
	A summary of the Company’s stock option activity and related information is as follows:
		Number of Shares			Weighted Average Exercise Price
	Outstanding at November 1, 2011		1,033,333			3
	Granted		88,000		$	4.5
	Exercised		-			-
	Cancelled		(75,000	)		3
	Outstanding at October 31, 2012		1,046,333		$	3.13
	Granted		--			--
	Exercised		-			-
	Cancelled		-			--
	Outstanding at October 31, 2013		1,046,333		$	3.13
	Exercisable at October 31, 2013		1,046,333		$	3.13
	The intrinsic value of the exercisable options at October 31, 2013 totaled $0. At October 31, 2013, the weighted average remaining life of the stock options is 6.35 years. At October 31, 2013, there was $63,204 of total unrecognized compensation cost related to the stock options granted under the plan. This cost is expected to be recognized over a weighted average period of 0.92 years.
	Warrants
	A summary of the Company’s stock warrant activity and related information for the years ended October 31, 2013 and 2012 is as follows:
		Warrants			Weighted Average Exercise Price
	Outstanding at November 1, 2011		2,390,601		$	4.71
	Granted		--			--
	Cancelled		--			--
	Outstanding at October 31, 2012		2,390,601		$	4.71
	Granted		--		$	--
	Cancelled		(333,333	)	$	6
	Outstanding at October 31, 2013		2,057,268		$	4.5
	The intrinsic value for the outstanding warrants at October 31, 2013 totaled $0. The remaining term of the warrants is 0.42 years.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Oct. 31, 2013
Notes to Financial Statements	'
Note 6. Commitments and Contingencies	'
	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 October 31, 2013, 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.
	In January 2012, the Company appointed a new director to the Board of Directors. In conjunction with this appointment, the Company entered into a compensation agreement with the director. Pursuant to this agreement, the director will receive cash compensation totaling $20,000 (paid quarterly) along with payment for attendance at Board meetings. In addition, the director will receive 25,000 shares of restricted Common Stock of the Company, of which 6,250 shares vest immediately and the remaining shares vest in semi-annual amounts of 3,125 shares. The Company also granted the director an option to purchase up to 88,000 shares of the Company’s common stock at an exercise price of $4.50 per share. The options vest equally over four years. During the year ended October 31, 2013, the Company recorded director expenses for the vesting of these shares totaling $24,793.
	Operating leases
	The Company leases its offices Texas on a month to month basis. Rent expense for the years ended October 31, 2013 and 2012 was $47,832 and $33,600, respectively.

Income_Taxes

Income Taxes	12 Months Ended
	Oct. 31, 2013
Notes to Financial Statements	'
Note 7. Income Taxes	'
	The reconciliation between the expected income tax benefit, computed using the statutory federal rate of 34%, and the actual income tax benefit is as follows:
		October 31,
		2013			2012
	Expected tax benefit at 34%	$	2,853,951		$	1,170,839
	Stock option expenses		(89,672	)		(202,260	)
	Miscellaneous		1,762			571,312
	Amortization of debt discount		(230,708	)		(24,100	)
	Change in valuation allowance		(2,535,333	)		(1,515,791	)
	Actual tax benefit	$	--		$	-
	The composition of deferred tax assets/liability is as follows:
		October 31,
		2013			2012
	Deferred Tax Asset
	Net operating loss	$	5,234,969		$	4,692,316
	Oil and gas properties		1,211,160
	Other		382,311			237,471
	Total deferred tax assets	$	6,828,440		$	4,929,787
	Deferred Tax Liability
	Oil and gas property interests		--			636,679
	Net deferred tax assets		6,828,440			4,293,108
	Valuation allowance		(6,828,440	)		(4,293,108	)
	Net	$	--		$	-
	The valuation allowance increased by $2,535,333 during the year ended October 2013. The Company established a valuation allowance to fully offset the net deferred income tax assets due to the uncertainty of the Company's ability to generate future taxable income necessary to realize these net deferred income tax assets, considering the Company's history of significant operating losses. In addition, future utilization of the available net operating loss carryforwards may be limited under Internal Revenue Code Section 382 as a result of any future changes in ownership.
	For federal income tax purposes, the Company has net operating losses of approximately $15,322,609 at October 31, 2013. These losses expire as follows:
	2026	$	291,662
	2027		1,739,955
	2028		1,265,101
	2029		769,546
	2030		588,394
	2031		5,153,072
	2032		3,748,939
	2033		1,765,940
		$	15,322,609

Supplemental_Oil_and_Gas_Discl

Supplemental Oil and Gas Disclosures	12 Months Ended
	Oct. 31, 2013
Notes to Financial Statements	'
Note 8. Supplemental Oil and Gas Disclosures (Unaudited)	'
	The following supplemental information regarding the oil and gas activities of the Company for 2013and 2012 is presented pursuant to the disclosure requirements promulgated by the Securities and Exchange Commission and ASC 932, "Disclosures About Oil and Gas Producing Activities." Capitalized costs relating to oil and gas activities and costs incurred in oil and gas property acquisition, exploration and development activities for each year are shown below.
	CAPITALIZED COST OF OIL AND GAS PRODUCING ACTIVITIES
	As of October 31		2013			2012
			United States			United States
	Unproved properties not being amortized		$	--		$	1,934,595
	Proved property being amortized			8,387,479			7,739,578
	Accumulated depreciation, depletion amortization and impairment			(6,309,607	)		(2,454,981	)
	Net capitalized costs		$	2,077,872		$	7,219,192
	COSTS INCURRED IN OIL AND GAS PROPERTY ACQUISITION, EXPLORATION, AND DEVELOPMENT ACTIVITIES
	As of October 31		2013			2012
	Property acquisition costs—proved and unproved properties		$	--		$	112,085
	Exploration costs		$	699,335		$	952,320
	Development costs		$	649,003		$	2,799,268
	OIL AND GAS RESERVES
	Users of this information should be aware that the process of estimating quantities of “proved” and “proved developed” oil and natural gas reserves is very complex, requiring significant subjective decisions in the evaluation of all available geological, engineering and economic data for each reservoir. The data for a given reservoir may also change substantially over time as a result of numerous factors including, but not limited to, additional development activity, evolving production history and continual reassessment of the viability of production under varying economic conditions. As a result, revisions to existing reserve estimates may occur from time to time. Although every reasonable effort is made to ensure reserve estimates reported represent the most accurate assessments possible, the subjective decisions and variances in available data for various reservoirs make these estimates generally less precise than other estimates included in the financial statement disclosures.
	Proved reserves represent estimated quantities of natural gas, crude oil and condensate that geological and engineering data demonstrate, with reasonable certainty, to be recoverable in future years from known reservoirs under economic and operating conditions in effect when the estimates were made. Proved developed reserves are proved reserves expected to be recovered through wells and equipment in place and under operating methods used when the estimates were made.
	The following table illustrates the Company’s estimated net proved reserves, including changes, and proved developed reserves for the periods indicated, as estimated by Hite & Associates and by Hamilton Group for the years ended October 31, 2013 and 2012, respectively. The oil and natural gas price as of October 31, 2013 and 2012 is based on the 12-month unweighted average of the first of the month prices of the West Texas Intermediate posted price. The oil and natural gas prices were adjusted by lease for quality, transportation fees, and regional price differentials. The gas price as of October 31, 2013 and 2012 is based on the 12-month unweighted average of the first of the month prices of the Henry Hub spot price. All prices are adjusted by lease for energy content, transportation fees, and regional price differentials. All prices are held constant in accordance with SEC guidelines. All proved reserves are located in the United States.
			Oil BBls			Gas Mcf
	31-Oct-11			1,644,390			1,843,660
	Revisions of previous estimates			(1,018,181	)		(500,057	)
	Acquisition of minerals in place			--			--
	Sales of minerals in place			(24,863	)		(800,620	)
	Production			(15,046	)		(32,893	)
	31-Oct-12			586,300			510,090
	Revisions of previous estimates			(511,801	)		(296,245	)
	Acquisition of minerals in place			--			--
	Sales of minerals in place			--			--
	Production			(16,139	)		(18,285	)
	31-Oct-13			58,360			195,560
	The Company's proved developed reserves are as follows:
			Developed						Undeveloped
			Oil BBls			Gas Mcf			Oil BBls		Gas Mcf
	31-Oct-13			58,360			195,560			--		--
	31-Oct-12			76,000			234,526			510,300		275,564
	31-Oct-11			82,300			1,062,610			1,562,090		781,050
	STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOW
	The following Standardized Measure of Discounted Future Net Cash Flow information has been developed utilizing ASC 932, Extractive Activities —Oil and Gas, (ASC 932) procedures and based on oil and natural gas reserve and production volumes estimated byHite & Associates. It can be used for some comparisons, but should not be the only method used to evaluate the Company or its performance. Further, the information in the following table may not represent realistic assessments of future cash flows, nor should the Standardized Measure of Discounted Future Net Cash Flow be viewed as representative of the current value of the Company.
	The Company believes that the following factors should be taken into account when reviewing the following information:
		•		future costs and selling prices will probably differ from those required to be used in these calculations;
		•		due to future market conditions and governmental regulations, actual rates of production in future years may vary significantly from the rate of production assumed in the calculations;
		•		a 10% discount rate may not be reasonable as a measure of the relative risk inherent in realizing future net oil and natural gas revenues; and
		•		future net revenues may be subject to different rates of income taxation.
	Under the Standardized Measure, for the years ended October 31, 2013 and 2012 the future cash inflows were estimated by applying the 12 month average of the oil and natural gas prices on the first day of the month ($92.60 and $91.06 for oil and $2.34 and $4.79 for natural gas for the years ended October 31, 2013 and 2012, respectively) to the estimated future production of year-end proved reserves. Estimates of future income taxes are computed using current statutory income tax rates including consideration for estimated future statutory depletion and tax credits. The resulting net cash flows are reduced to present value amounts by applying a 10% discount factor. Use of a 10% discount rate and year-end prices were required. At October 31, 2013 and 2012, as specified by the SEC, the prices for oil and natural gas used in this calculation were the unweighted 12-month average of the first day of the month (12-month unweighted average) cash price quotes, except for volumes subject to fixed price contracts.
			2013			2012
	Future cash inflows		$	6,077,480		$	55,667,980
	Future development costs			(321,400	)		(20,458,060	)
	Future production costs			(2,940,800	)		(14,983,390	)
	Future income tax expenses			-			-
	Future net cash flows before 10% discount			2,815,280			20,226,530
	10%Annual discount for estimated timing of cash flows			(713,950	)		(12,543,920	)
	Standardized measure discounted future net cash flows		$	2,101,330		$	7,682,610
	CHANGES IN STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS
	The following is a summary of the changes in the Standardized Measure of discounted future net cash flows for the Company’s proved oil and natural gas reserves during each of the years in the two year period ended October 31, 2013:
			2013			2012
	Beginning of the year		$	7,682,610		$	17,017,670
	Sales and transfers of oil and gas produced, net of production costs			(924,607	)		(818,959	)
	Net changes in prices and production costs			(6,104,363	)		503,507
	Net changes in income taxes			-			-
	Development costs incurred			647,901			2,817,119
	Changes in estimated future development costs, net of current development costs			16,571,027			20,444,800
	Acquisition of minerals in place			--			(789,570	)
	Revision of previous estimates			(12,918,359	)		(33,359,836	)
	Change of discount			768,261			1,701,767
Change in production rate and other			(3,621,140	)		166,112
End of year		$	2,101,330		$	7,682,610

Subsequent_Events

Subsequent Events	12 Months Ended
	Oct. 31, 2013
Notes to Financial Statements	'
Note 9 - Subsequent Events	'
	Adwar II Development Agreement
	In February 2014, the Company amended its development agreement with Adwar Drilling Fund II, LP. (“Adwar II”). Pursuant to the amendment, Adwar II agreed to purchase up to a 37.5% working interest in the three wells drilled in November 2013 in the AP Clark Field, and up to a 18.75% working interest in a well to be drilled in the future. In February 2014, Adwar II delivered $300,000 toward the purchase of a working interest in the three wells, along with $30,000 of upfront monies. Adwar II has until March 31, 2014 to raise additional funds to increase its working interest in the project. Their final ownership percentage in the wells will be calculated at that time.

The_Company_and_Summary_of_Sig1

The Company and Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Oct. 31, 2013
Company And Summary Of Significant Accounting Policies Policies	'
Description of business and history	'
	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.
Principles of consolidation	'
	The consolidated financial statements include the accounts of the Company and its wholly-owned subsidiaries, NRG Asset Management LLC, Copano Bay Holdings LLC, APClark LLC and BSPE Texas, LLC.All significant inter-company transactions and balances have been eliminated.
Oil and Gas Properties	'
	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 proved 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 filed 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.
	During the years ended October 31, 2013 and 2012, the Company impaired its oil and gas properties by $4,820,770 and $225,543, which is reflected in the consolidated statement of operations (see Note 2).
Asset Retirement Obligation	'
	The Company follows ASC 410—Asset Retirement and Environmental Obligations which requires entities to record the fair value of a liability for legal obligations associated with the retirement obligations of tangible long-lived assets in the period in which it is incurred. This standard requires the Company to record a liability for the fair value of the dismantlement and plugging and abandonment costs excluding salvage values. When the liability is initially recorded, the entity increases the carrying amount of the related long-lived asset. Over time, accretion of the liability is recognized each period and the capitalized cost is amortized over the useful life ofthe related asset. Upon settlement of the liability, an entity either settles the obligation for its recorded amount or incurs a gain or loss upon settlement.
Accounting for Derivative Instruments	'
	ASC 815-24 (formerly SFAS No. 133, “Accounting for Derivative Instruments and Hedging Activities,”), requires all derivatives to be recorded on the balance sheet at fair value. The Company’s derivatives are separately valued and accounted for on the balance sheet. Fair values for securities traded in the open market and derivatives are based on quoted market prices. Where market prices are not readily available, fair values are determined using market based pricing models incorporating readily observable market data and requiring judgment and estimates.
	The pricing model the Company used for determining fair values of its derivatives is the Black-Scholes option-pricing model. Valuations derived from this model are subject to ongoing internal and external verification and review. The model uses market-sourced inputs such as interest rates, exchange rates and option volatilities. Selection of these inputs involves management’s judgment and may impact net income.
Cash and cash equivalents and short term investments	'
	Cash and cash equivalents include cash on account and all highly liquid investments with original maturities of three months or less on the date of acquisition. Investments with original maturities of greater than three months but less than one year are considered short-term investments.
Use of estimates	'
	The preparation of consolidated financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Actual results could differ from those estimates.
	The most critical estimate is the engineering estimate of proved oil and gas reserves. This estimate affects the application of the successful efforts method of accounting, the calculation of depreciation, depletion and amortization of the oil and gas properties and the estimate of the impairment of the oil and gas properties. It also affects the estimated lives used to determine asset retirement obligations. In addition, the estimates of proved oil and gas reserves are the basis for the related standardized measure of discounted future cash flows.
Concentration of credit risks	'
	The Company’s consolidated financial assets that are exposed to credit risk consist primarily of cash and cash equivalents and accounts receivable. The Company maintained substantially all of its cash balances in a limited number of financial institutions. The balances are insured by the Federal Deposit Insurance Corporation up to $250,000. The Company had $749,965 in excess of this limit at October 31, 2013.
Property and equipment	'
	Property and equipment are stated at cost less accumulated depreciation. Depreciation is provided principally on the straight-line method over the estimated useful lives of the assets, which are generally 3 to 27 years. The amounts of depreciation provided are sufficient to charge the cost of the related assets to operations over their estimated useful lives. Upon sale or other disposition of a depreciable property, cost and accumulated depreciation are removed from the accounts and any gain or loss is reflected in the statement of operations.
	The Company periodically evaluates whether events and circumstances have occurred that may warrant revision of the estimated useful life of fixed assets or whether the remaining balance of fixed assets should be evaluated for possible impairment. The Company uses an estimate of the related undiscounted cash flows over the remaining life of the fixed assets in measuring their recoverability.
Revenue recognition	'
	Revenue is recognized when title to the products transfer to the purchaser. The Company uses the “sales method” to account for production revenue, whereby revenue is recognized on all oil, natural gas or other related products sold to our purchasers, regardless of whether the sales are proportionate to our ownership in the property. A receivable or liability is recognized only to the extent that there is an imbalance on a specific property greater than the expected remaining proved reserves. As of October 31, 2013, our aggregate production imbalances were not material.
Stock-based compensation	'
	The Company follows the provisions of FASB ASC 718—Stock Compensation. The statement requires all stock-based payments to employees, including grants of employee stock options, to be recognized in the financial statements based on their fair values on the date of grant.
Income taxes	'
	The Company accounts for its income taxes in accordance with ASC 740 Income Taxes, which requires recognition of deferred tax assets and liabilities for future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and tax credit carry forwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in operations in the period that includes the enactment date.A valuation allowance is provided for the amount of deferred tax assets that would otherwise be recorded for income tax benefits primarily relating to operating loss carryforwards as realization cannot be determined to be more likely than not.
	The statement establishes a more-likely-than-not threshold for recognizing the benefits of tax return positions in the financial statements. Also, the statement implements a process for measuring those tax positions which meet the recognition threshold of being ultimately sustained upon examination by the taxing authorities. There are no uncertain tax positions taken by the Company on its tax returns and the adoption of the statement had no material impact to the Company’s consolidated financial statements. The Company files tax returns in the US and states in which it has operations and is subject to taxation. Tax years subsequent to 2009 remain open to examination by U.S. federal and state tax jurisdictions.
Net loss per common share	'
	The Company computes net income or loss per share in accordance with ASC 260 Earnings Per Share. Under the provisions of the Earnings per Share Topic ASC, basic net loss per share is computed by dividing the net loss available to common stockholders for the period by the weighted average number of shares of common stock outstanding during the period. The calculation of diluted net loss per share gives effect to common stock equivalents; however, potential common shares are excluded if their effect is anti-dilutive. The weighted average number of potentially dilutive common shares excluded from the calculation of diluted net income (loss) per share totaled 3,103,601 and 3,511,934 for the years ended October 31, 2013 and 2012, respectively.
Fair Value of Financial Instruments	'
	The carrying amounts of financial instruments, including cash and cash equivalents, short-term investments, accounts receivable, accounts payable and accrued liabilities approximate fair value at October 31, 2013 and October 31, 2012 because of the short period to maturity of these instruments.
Going Concern	'
	As shown in the accompanying consolidated financial statements, the Company has incurred an accumulated deficit of $28,707,810 through October 31, 2013. In addition, the Company had a working capital deficit of $2,172,431 and cash and cash equivalents of $1,335,237 at October 31, 2013. A substantial portion of the cash available at October 31, 2013 was used toward the drilling costs for the three new wells drilled 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 on 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.
Reclassification	'
	During the quarter ended January 31, 2013, the Company discovered and corrected an error regarding its reporting for certain unvested option costs for a former employee. The error resulted in an overstatement of its general and administrative expenses and net losses and an overstatement of its additional paid in capital during the year ended October 31, 2012 by $145,482. In addition, the change reduced the net loss per share by $.01.

Oil_and_Gas_Property_Costs_Tab

Oil and Gas Property Costs (Tables)	12 Months Ended
	Oct. 31, 2013
Oil And Gas Property Costs Tables	'
Property acquisition costs	'
	In the years ended October 31, 2013 and October 31, 2012, the Company incurred property acquisition costs as follows:
	Proved Properties
		2013			2012
	Balance, beginning of year	$	5,284,597		$	5,360,478
	Costs incurred during the year		647,901			862,407
	Asset retirement obligation acquired		--			33,128
	Depletion		(968,451	)		-656,411
	Impairment of oil and gas property costs		(2,886,175	)		(147,370	)
	Cost of property sold		--			(167,635	)
	Balance, end of year	$	2,077,872		$	5,284,597
	Unproved Properties
		2013			2012
	Balance, beginning of year	$	1,934,595		$	2,012,768
	Costs incurred during the year		--			--
	Impairment of oil and gas property costs		(1,934,595	)		(78,173	)
	Balance, end of year	$	--		$	1,934,595
Proforma information	'
	The following is a summary of the proforma information assuming the sale of the Copano Bay field had occurred as of the beginning of each fiscal year presented:
		2013			2012
	Oil and gas revenues	$	1,690,249		$	1,343,951
	Expenses
	Selling, general and administrative		1,443,223			1,829,078
	Depreciation and depletion		969,511			644,110
	Accretion		39,731			38,136
	Lease operating expense		765,643			581,344
	Impairment of oil and gas properties		4,820,770			225,543
	Oil and gas exploration costs		699,335			952,320
	Total expenses		8,738,213			4,270,531
	Loss from operations		(7,047,964	)		(2,926,580	)
	Other income (expense)		(1,346,010	)		(449,881	)
	Net income	$	(8,393,974	)	$	(3,376,461	)

Debt_Tables

Debt (Tables)	12 Months Ended
	Oct. 31, 2013
Debt Tables	'
Debt outstanding	'
	The following is a summary of the debt outstanding at October 31,
		2013			2012
	Silver Bullet Properties	$	3,220,000		$	3,000,000
	PIE Energy		60,000			60,000
	KP-RAHR Ventures III, LLC, net
	of discount of $1,329,581 and $2,008,134		1,270,419			591,866
	Total		4,550,419			3,651,866
	Less current maturities		280,000			60,000
	Long-term debt	$	4,270,419		$	3,591,866
Date of Repayment	'
	Date of Repayment in Full	NPI %
	On or prior to six month anniversary		7.5	%
	After six months but on or prior to two year anniversary		15	%
	After two years but on or prior to three year anniversary		20	%
	After three years		50	%

Asset_Retirement_Obligation_Ta

Asset Retirement Obligation (Tables)	12 Months Ended
	Oct. 31, 2013
Asset Retirement Obligation Tables	'
Change in the asset retirement obligation	'
	The following table summarizes the change in the asset retirement obligation (“ARO”) for the years ended October 31,
		2013		2012
	Beginning balance at November 1	$	609,502	$	677,318
	Liabilities settled		--		--
	Liabilities incurred through acquisition of assets		--		--
	Liabilities transferred through sale of assets		--		(154,664	)
	Change in estimate of well life		--		33,128
	Accretion expense		39,731		53,720
	Ending balance at October 31	$	649,233	$	609,502

Stockholders_Equity_Tables

Stockholders Equity (Tables)	12 Months Ended
	Oct. 31, 2013
Stockholders Equity Tables	'
Stock Options Activity	'
	A summary of the Company’s stock option activity and related information is as follows:
		Number of Shares			Weighted Average Exercise Price
	Outstanding at November 1, 2011		1,033,333			3
	Granted		88,000		$	4.5
	Exercised		-			-
	Cancelled		(75,000	)		3
	Outstanding at October 31, 2012		1,046,333		$	3.13
	Granted		--			--
	Exercised		-			-
	Cancelled		-			--
	Outstanding at October 31, 2013		1,046,333		$	3.13
	Exercisable at October 31, 2013		1,046,333		$	3.13
Stock Warrant Activity	'
	A summary of the Company’s stock warrant activity and related information for the years ended October 31, 2013 and 2012 is as follows:
		Warrants			Weighted Average Exercise Price
	Outstanding at November 1, 2011		2,390,601		$	4.71
	Granted		--			--
	Cancelled		--			--
	Outstanding at October 31, 2012		2,390,601		$	4.71
	Granted		--		$	--
	Cancelled		(333,333	)	$	6
	Outstanding at October 31, 2013		2,057,268		$	4.5

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Oct. 31, 2013
Income Taxes Tables	'
Reconciliation between the expected income tax benefit and statutory federal rate	'
	The reconciliation between the expected income tax benefit, computed using the statutory federal rate of 34%, and the actual income tax benefit is as follows:
		October 31,
		2013			2012
	Expected tax benefit at 34%	$	2,853,951		$	1,170,839
	Stock option expenses		(89,672	)		(202,260	)
	Miscellaneous		1,762			571,312
	Amortization of debt discount		(230,708	)		(24,100	)
	Change in valuation allowance		(2,535,333	)		(1,515,791	)
	Actual tax benefit	$	--		$	-
Deferred tax assets/liability	'
	The composition of deferred tax assets/liability is as follows:
		October 31,
		2013			2012
	Deferred Tax Asset
	Net operating loss	$	5,234,969		$	4,692,316
	Oil and gas properties		1,211,160
	Other		382,311			237,471
	Total deferred tax assets	$	6,828,440		$	4,929,787
	Deferred Tax Liability
	Oil and gas property interests		--			636,679
	Net deferred tax assets		6,828,440			4,293,108
	Valuation allowance		(6,828,440	)		(4,293,108	)
	Net	$	--		$	-
Net operating losses	'
	For federal income tax purposes, the Company has net operating losses of approximately $15,322,609 at October 31, 2013. These losses expire as follows:
	2026	$	291,662
	2027		1,739,955
	2028		1,265,101
	2029		769,546
	2030		588,394
	2031		5,153,072
	2032		3,748,939
	2033		1,765,940
		$	15,322,609

Supplemental_Oil_and_Gas_Discl1

Supplemental Oil and Gas Disclosures (Unaudited) (Tables)	12 Months Ended
	Oct. 31, 2013
Supplemental Oil And Gas Disclosures Tables	'
Capitalized Cost Of Oil And Gas Producing Activities	'
	CAPITALIZED COST OF OIL AND GAS PRODUCING ACTIVITIES
	As of October 31	2013			2012
		United States			United States
	Unproved properties not being amortized	$	--		$	1,934,595
	Proved property being amortized		8,387,479			7,739,578
	Accumulated depreciation, depletion amortization and impairment		(6,309,607	)		(2,454,981	)
	Net capitalized costs	$	2,077,872		$	7,219,192
Costs Incurred In Oil And Gas Property Acquisition, Exploration, And Development Activities	'
	COSTS INCURRED IN OIL AND GAS PROPERTY ACQUISITION, EXPLORATION, AND DEVELOPMENT ACTIVITIES
	As of October 31	2013			2012
	Property acquisition costs—proved and unproved properties	$	--		$	112,085
	Exploration costs	$	699,335		$	952,320
	Development costs	$	649,003		$	2,799,268
Oil And Gas Reserves	'
		Oil BBls			Gas Mcf
	31-Oct-11		1,644,390			1,843,660
	Revisions of previous estimates		(1,018,181	)		(500,057	)
	Acquisition of minerals in place		--			--
	Sales of minerals in place		(24,863	)		(800,620	)
	Production		(15,046	)		(32,893	)
	31-Oct-12		586,300			510,090
	Revisions of previous estimates		(511,801	)		(296,245	)
	Acquisition of minerals in place		--			--
	Sales of minerals in place		--			--
	Production		(16,139	)		(18,285	)
	31-Oct-13		58,360			195,560
Proved developed reserves	'
	The Company's proved developed reserves are as follows:
		Developed						Undeveloped
		Oil BBls			Gas Mcf			Oil BBls		Gas Mcf
	31-Oct-13		58,360			195,560			--		--
	31-Oct-12		76,000			234,526			510,300		275,564
	31-Oct-11		82,300			1,062,610			1,562,090		781,050
Standardized Measure Of Discounted Future Net Cash Flow	'
		2013			2012
	Future cash inflows	$	6,077,480		$	55,667,980
	Future development costs		(321,400	)		(20,458,060	)
	Future production costs		(2,940,800	)		(14,983,390	)
	Future income tax expenses		-			-
	Future net cash flows before 10% discount		2,815,280			20,226,530
	10%Annual discount for estimated timing of cash flows		(713,950	)		(12,543,920	)
	Standardized measure discounted future net cash flows	$	2,101,330		$	7,682,610
Changes In Standardized Measure Of Discounted Future Net Cash Flows	'
	The following is a summary of the changes in the Standardized Measure of discounted future net cash flows for the Company’s proved oil and natural gas reserves during each of the years in the two year period ended October 31, 2013:
		2013			2012
	Beginning of the year	$	7,682,610		$	17,017,670
	Sales and transfers of oil and gas produced, net of production costs		(924,607	)		(818,959	)
	Net changes in prices and production costs		(6,104,363	)		503,507
	Net changes in income taxes		-			-
	Development costs incurred		647,901			2,817,119
	Changes in estimated future development costs, net of current development costs		16,571,027			20,444,800
	Acquisition of minerals in place		--			(789,570	)
	Revision of previous estimates		(12,918,359	)		(33,359,836	)
	Change of discount		768,261			1,701,767
	Change in production rate and other		(3,621,140	)		166,112
	End of year	$	2,101,330		$	7,682,610

The_Company_and_Summary_of_Sig2

The Company and Summary of Significant Accounting Policies (Details Narrative) (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012
Company And Summary Of Significant Accounting Policies Details Narrative	'	'
Impairment of oil and gas property interest	$4,820,770	$225,543
Potentially dilutive common shares excluded from the calculation of diluted net income (loss)	3,103,601	3,511,934
Accumulated deficit	-28,707,810	-20,313,836
Working capital deficit	2,172,431	'
Cash and cash equivalents	1,335,237	'
Overstatement Additional paid in capital	'	$145,482

Oil_and_Gas_Property_Costs_Det

Oil and Gas Property Costs (Details) (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012
Proved Properties [Member]	'	'
Balance, beginning of year	$5,284,597	$5,360,478
Costs incurred during the year	647,901	862,407
Asset retirement obligation acquired	'	33,128
Depletion	-968,451	-656,411
Impairment of oil and gas property costs	-2,886,175	-147,370
Cost of property sold	'	-167,635
Balance, end of year	2,077,872	5,284,597
Unproved Properties [Member]	'	'
Balance, beginning of year	1,934,595	2,012,768
Costs incurred during the year	'	'
Impairment of oil and gas property costs	-1,934,595	-78,173
Balance, end of year	'	$1,934,595

Oil_and_Gas_Property_Costs_Det1

Oil and Gas Property Costs (Details 1) (Copano Bay [Member], USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012
Copano Bay [Member]	'	'
Oil and gas revenues	$1,690,249	$1,343,951
Expenses	'	'
Selling, general and administrative	1,443,223	1,829,078
Depreciation and depletion	969,511	644,110
Accretion	39,731	38,136
Lease operating expense	765,643	581,344
Impairment of oil and gas properties	4,820,770	225,543
Oil and gas exploration costs	699,335	952,320
Total expenses	8,738,213	4,270,531
Loss from operations	-7,047,964	-3,072,062
Other income (expense)	-1,346,010	-449,881
Net income	($8,393,974)	($3,376,461)

Oil_and_Gas_Property_Costs_Det2

Oil and Gas Property Costs (Details Narrative) (USD $)	12 Months Ended
	Oct. 30, 2012	Oct. 30, 2012	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2013	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2013	Oct. 31, 2013
	Livestock 7-1 [Member]	Livestock 18-1 [Member]	Unproved Properties [Member]	Unproved Properties [Member]	Unproved Properties [Member]	Proved Properties [Member]	Proved Properties [Member]	Proved Properties [Member]	Proved Properties [Member]
					Del Norte Acquisition [Member]			AP Clark Wells [Member]	Cabeza Creek Field [Member]
Impairment	'	'	$1,934,595	$78,173	$153,381	$2,886,175	$147,370	$2,881,816	$4,359
Drilled wells cost	$1,223,535	$1,275,699	$171,790	$952,320	'	'	'	'	'

Debt_Details

Debt (Details) (USD $)	Oct. 31, 2013	Oct. 31, 2012
Total	$4,550,419	$3,651,866
Less current maturities	280,000	60,000
Long-term debt	4,270,419	3,591,866
KP-RAHR Ventures III, LLC	'	'
Total	1,270,419	591,866
Silver Bullet Properties [Member]	'	'
Total	3,220,000	3,000,000
PIE Energy [Member]	'	'
Total	$60,000	$60,000

Debt_Details_1

Debt (Details 1)	12 Months Ended
	Oct. 31, 2013
Date of Repayment in Full	'
On or prior to six month anniversary	7.50%
After six months but on or prior to two year anniversary	15.00%
After two years but on or prior to three year anniversary	20.00%
After three years	50.00%

Debt_Details_Narrative

Debt (Details Narrative) (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012
Debt Details Narrative	'	'
Fair value of the overriding royalties	$163,786	'
Net profits interest	1,915,231	'
Carrying value of the discounts	1,329,581	'
Amortization of interest expense	$678,553	$70,883

Asset_Retirement_Obligation_De

Asset Retirement Obligation (Details) (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012
Asset Retirement Obligation Details	'	'
Beginning balance	$609,502	$677,318
Liabilities settled	'	'
Liabilities incurred through acquisition of assets	'	'
Liabilities transferred through sale of assets	'	-154,664
Change in estimate of well life	'	33,128
Accretion expense	39,731	53,720
Ending balance	$649,233	$609,502

Stockholders_Equity_Details

Stockholders Equity (Details) (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012
Number of Shares	'	'
Beginning Balance	1,046,333	1,033,333
Granted	'	88,000
Exercised	'	'
Cancelled	'	-75,000
Ending Balance	1,046,333	1,046,333
Exercisable at October 31, 2013	1,046,333	'
Weighted Average Exercise Price	'	'
Beginning Balance	$3.13	$3
Granted	'	$4.50
Exercised	'	'
Cancelled	'	$3
Ending Balance	$3.13	$3.13
Exercisable at October 31, 2013	$3.13	'

Stockholders_Equity_Details_1

Stockholders' Equity (Details 1) (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012
Notes to Financial Statements	'	'
Warrants, Outstanding at November 1, 2011	2,390,601	2,390,601
Warrants Granted	'	'
Warrants Cancelled	-333,333	'
Warrants, Outstanding at October 31, 2012	2,057,268	2,390,601
Weighted Average Exercise Price, Beggining Balance	$4.71	$4.71
Granted Weighted Average Exercise Price	'	'
Cancelled Weighted Average Exercise Price	$6	'
Outstanding at October 31, 2013	4.5	4.71

Stockholders_Equity_Details_Na

Stockholders Equity (Details Narrative) (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012
Stockholders Equity Details Narrative	'	'
Preferred stock, par value	$0.00	$0.01
Preferred stock, authorized shares	10,000,000	10,000,000
Series A Preferred stock, outstanding shares	826,667	'
Stock options were granted to a director	'	88,000
Exercise price of the options	'	$4.50
Expected volatility	'	134.00%
Risk free interest rate	'	0.77%
Expected lives	'	'3 years 8 months 12 days
Stock-based compensation expenses	$238,980	$449,419
Intrinsic value of the exercisable options	0	'
Weighted average remaining life of the stock options	'6 years 4 months 6 days	'
Total unrecognized compensation cost related to the stock options granted	63,204	'
Weighted average period	'11 months 1 day	'
Intrinsic value for the outstanding warrants	$0	'
Remaining term of the warrants	'5 months 1 day	'

Commitments_and_Contingencies_

Commitments and Contingencies (Details Narrative) (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012
Commitments And Contingencies Details Narrative	'	'
Director expenses	$24,793	'
Rent expense	$47,832	$33,600

Income_Taxes_Details

Income Taxes (Details) (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012
Income Taxes Details	'	'
Expected tax benefit at 34%	$2,853,951	$1,170,839
Stock option expenses	-89,672	-202,260
Miscellaneous	1,762	571,312
Amortization of debt discount	-230,708	-24,100
Change in valuation allowance	2,535,333	-1,515,791
Actual tax benefit	'	'

Income_Taxes_Details_1

Income Taxes (Details 1) (USD $)	Oct. 31, 2013	Oct. 31, 2012
Deferred Tax Asset	'	'
Net operating loss	$5,234,969	$4,692,316
Oil and gas properties	1,211,160	'
Other	382,311	237,471
Total deferred tax assets	6,828,440	4,929,787
Deferred Tax Liability	'	'
Oil and gas property interests	'	636,679
Net deferred tax assets	6,828,440	4,293,108
Valuation allowance	-6,828,440	-4,293,108
Net	'	'

Income_Taxes_Details_2

Income Taxes (Details 2) (USD $)	Oct. 31, 2013
Operating Loss Carry forwards	$15,322,609
2026	'
Operating Loss Carry forwards	291,662
2027	'
Operating Loss Carry forwards	1,739,955
2028	'
Operating Loss Carry forwards	1,265,101
2029	'
Operating Loss Carry forwards	769,546
2030	'
Operating Loss Carry forwards	588,394
2031	'
Operating Loss Carry forwards	5,153,072
2032	'
Operating Loss Carry forwards	3,926,547
2033	'
Operating Loss Carry forwards	$1,765,940

Income_Taxes_Details_Narrative

Income Taxes (Details Narrative) (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012
Income Taxes Details Narrative	'	'
Statutory federal rate	34.00%	'
Change in valuation allowance	$2,535,333	($1,515,791)

Supplemental_Oil_and_Gas_Discl2

Supplemental Oil and Gas Disclosures (Unaudited) (Details) (USD $)	Oct. 31, 2013	Oct. 31, 2012
		United States
CAPITALIZED COST OF OIL AND GAS PRODUCING ACTIVITIES	'	'
Unproved properties not being amortized	'	$1,934,595
Proved property being amortized	8,387,479	7,739,578
Accumulated depreciation, depletion amortization and impairment	-6,309,607	-2,454,981
Net capitalized costs	$2,077,872	$7,219,192

Supplemental_Oil_and_Gas_Discl3

Supplemental Oil and Gas Disclosures (Unaudited) (Details 1) (USD $)	Oct. 31, 2013	Oct. 31, 2012
COSTS INCURRED IN OIL AND GAS PROPERTY ACQUISITION, EXPLORATION, AND DEVELOPMENT ACTIVITIES	'	'
Property acquisition costs proved and unproved properties	'	$112,085
Exploration costs	699,335	952,320
Development costs	$649,003	$2,799,268

Supplemental_Oil_and_Gas_Discl4

Supplemental Oil and Gas Disclosures (Unaudited) (Details 2)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012
	bbl	bbl
Oil BBls Member	'	'
Begnning Balance	586,300	1,644,390
Revisions of previous estimates	-511,801	-1,018,181
Sales of minerals in place	'	-24,863
Production	16,139	-15,046
Ending Balance	58,360	586,300
Gas Mcf Member	'	'
Begnning Balance	510,090	1,843,660
Revisions of previous estimates	-296,245	-500,057
Sales of minerals in place	'	-800,620
Production	-18,285	-32,893
Ending Balance	195,560	510,090

Supplemental_Oil_and_Gas_Discl5

Supplemental Oil and Gas Disclosures (Unaudited) (Details 3)	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2011
	bbl	bbl	bbl
Oil BBls Member	'	'	'
Developed Reserves	58,360	76,000	82,300
Undeveloped Reserves	'	510,300	1,562,090
Gas Mcf Member	'	'	'
Developed Reserves	195,560	234,526	1,062,610
Undeveloped Reserves	'	275,564	781,050

Supplemental_Oil_and_Gas_Discl6

Supplemental Oil and Gas Disclosures (Unaudited) (Details 4) (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012
Notes to Financial Statements	'	'
Future cash inflows	$6,077,480	$55,667,980
Future development costs	-321,400	-20,458,060
Future production costs	-2,940,800	-14,983,390
Future income tax expenses	'	'
Future net cash flows before 10% discount	2,815,280	20,226,530
10%Annual discount for estimated timing of cash flows	-713,950	-12,543,920
Standardized measure discounted future net cash flows	$2,101,330	$7,682,610

Supplemental_Oil_and_Gas_Discl7

Supplemental Oil and Gas Disclosures (Unaudited) (Details 5) (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012
Notes to Financial Statements	'	'
Beginning of the year	$7,682,610	$17,017,670
Sales and transfers of oil and gas produced, net of production costs	-924,607	-818,959
Net changes in prices and production costs	-6,104,363	503,507
Net changes in income taxes	'	'
Development costs incurred	647,901	2,817,119
Changes in estimated future development costs, net of current development costs	16,571,027	20,444,800
Acquisition of minerals in place	'	-789,570
Revision of previous estimates	-12,918,359	-33,359,836
Change of discount	768,261	1,701,767
Change in production rate and other	-3,621,140	166,112
End of year	$2,101,330	$7,682,610