Diversified Resources 10-K/A 20 Feb 15 2014 FY Annual report (amended) Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Oct. 31, 2014	Apr. 30, 2014
Document and Entity Information:
Entity Registrant Name	Diversified Resources Inc.
Document Type	10-K
Document Period End Date	31-Oct-14
Amendment Flag	TRUE
Amendment Description	Amendment 1
Entity Central Index Key	1509692
Current Fiscal Year End Date	-21
Entity Common Stock, Shares Outstanding		18,445,867
Entity Public Float		$0
Entity Filer Category	Smaller Reporting Company
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Well-known Seasoned Issuer	No
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Oct. 31, 2014		Oct. 31, 2013
CURRENT ASSETS
Cash	$209,054		$69,433
Accounts receivable, trade	130,495		32,378
Prepaid expenses	7,948		8,870
Total current assets	347,497		110,681
Property and Equipment	1,904,403	[1]	39,392	[2]
Bonds and deposits	167,867
Oil and gas properties - proved (successful efforts method)	3,806,153	[3]	2,604,418	[4]
Oil and gas properties - proved undeveloped (successful efforts method)	1,209,724		64,126
Oil and gas properties - unproved (successful efforts method)	2,932,730
Total assets	10,368,374		2,818,617
CURRENT LIABILITIES
Accounts payable	221,880		185,251
Accounts payable, related party	145,473		130,361
Current portion of installment loan	373,846		304,071
Accrued interest, related party	4,579		3,872
Accrued expenses	560,548		111,604
Total current liabilities	1,306,326		735,159
Long term debt, related party	107,070		107,070
Long term debt, installment loan	2,294,943		13,765
Asset retirement obligation	290,312		222,375
STOCKHOLDERS' EQUITY
Common stock	22,502		14,563
Additional paid in capital	8,629,554		4,734,138
Accumulated deficit	-2,282,333		-3,008,453
Total stockholders' equity	6,369,723		1,740,248
Total liabilities and stockholders' equity	$10,368,374		$2,818,617
[1]	Net of accumulated depreciation of $149,957.
[2]	Net of accumulated depreciation of $4,111.
[3]	Net of accumulated depletion of $100,062.
[4]	Net of accumulated depletion of $56,726.

Statement_of_Financial_Positio

Statement of Financial Position - Parenthetical (USD $)	Oct. 31, 2014	Oct. 31, 2013
Statement of Financial Position
Preferred Stock, Par Value	$0.00	$0.00
Preferred Stock, Shares Authorized	50,000,000	50,000,000
Preferred Stock, Shares Issued	0	0
Preferred Stock, Shares Outstanding	0	0
Common Stock, Par Value	$0.00	$0.00
Common Stock, Shares Authorized	450,000,000	450,000,000
Common Stock, Shares Issued	22,502,206	14,558,150
Common Stock, Shares Outstanding	22,502,206	14,558,150

CONSOLIDATED_STATEMENTS_OF_OPE

CONSOLIDATED STATEMENTS OF OPERATIONS (For the Years Ended October 31, 2014 and October 31, 2013) (USD $)	12 Months Ended
	Oct. 31, 2014	Oct. 31, 2013
Operating revenues
Oil and gas sales	$161,623	$85,808
Consulting fees		10,347
Total operating revenues	161,623	96,155
Operating expenses
Exploration costs, including dry holes	41,802	69,878
Lease operating expenses	290,588	189,212
General and administrative	1,510,367	494,845
Depreciation expense	27,895	7,641
Depletion expense	34,475	13,800
Production tax and royalty expense	30,225
Accretion expense	24,054	20,800
Total operating expenses	1,959,406	796,176
(Loss) from operations	-1,797,783	-700,021
Other income (expense)
Loss on debt extinguishment		-330,638
Loss on disposition of assets		-13,158
Bargain purchase gain	2,584,184
Interest expense	-60,281	-126,586
Other income (expense), net	2,523,903	-470,382
Net income (loss)	$726,120	($1,170,403)
Net (loss) per common share basic and diluted	$0.04	($0.09)
Weighted average shares outstanding basic and diluted	18,792,650	13,684,623

Consolidated_Statement_of_Stoc

Consolidated Statement of Stockholders' Equity (Years Ended October 31, 2013 and 2014) (USD $)	Preferred Stock	Common Stock	Additional Paid-in Capital	Accumulated Deficit	Total
Balance, Value at Oct. 31, 2012	$49,992	$13,094	$3,472,978	($1,838,050)	$1,698,014
Balance, Shares at Oct. 31, 2012	208,820	13,093,703
Conversion of preferred stock to common stock, Value	-49,992	209	49,783
Conversion of preferred stock to common stock, Shares	-208,820	208,820
Conversion of debt to common stock, Value		396	395,481		395,877
Conversion of debt to common stock, Shares		395,877			395,877
Common stock issued for cash, Value		859	815,901		816,760
Common stock issued for cash, Shares		859,750			859,750
Profit (loss)				-1,170,403	-1,170,403
Balance, Value at Oct. 31, 2013		14,558	4,734,143	-3,008,453	1,740,248
Balance, Shares at Oct. 31, 2013		14,558,150			14,558,150
Common stock issued for cash, Value		4,474	2,925,172		2,929,646
Common stock issued for cash, Shares		4,474,089			4,474,089
Recapitalization with Natural Resources Group, Inc., Value		5,250	-302,980		-297,730
Recapitalization with Natural Resources Group, Inc., Shares		5,250,000
Contribution of shares in connection with the acquisition, Value		-2,680	2,680
Contribution of shares in connection with the acquisition, Shares		-2,680,033
Forgiveness of related party debt and assumption of liabilities by former shareholder, Value			297,741		297,741
Acquisition of BIYA, Value		900	972,798		973,698
Acquisition of BIYA, Shares		900,000
Profit (loss)				726,120	726,120
Balance, Value at Oct. 31, 2014		$22,502	$8,629,554	($2,282,333)	$6,369,723
Balance, Shares at Oct. 31, 2014		22,502,206			22,502,206

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (For the Years Ended October 31, 2014 and October 31, 2013) (USD $)	12 Months Ended
	Oct. 31, 2014	Oct. 31, 2013
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	$726,120	($1,170,403)
Bargain purchase gain (increase/decrease)	-2,584,184
Depreciation expense	27,895	7,641
Depletion expense	34,475	13,800
Accretion expense	24,054	20,800
Amortization of discount on notes payable		75,993
Loss on debt extinguishment (increase/decrease)		330,638
Loss on sale of assets (increase/decrease)		13,158
Accounts receivable, trade (increase/decrease)	34,860	-18,097
Prepaid expense (increase/decrease)	11,924	-3,167
Bonds and deposits (increase/decrease)	21,042
Accounts payable (increase/decrease)	2,731	96,234
Accounts payable - related parties (increase/decrease)	15,112	38,066
Accrued expenses (increase/decrease)	-819,829	-3,974
Net cash (used in) operating activities	-2,505,800	-599,311
CASH FLOWS FROM INVESTING ACTIVITIES:
Proceeds from sale of assets (increase/decrease)		65,583
Cash paid for oil and gas properties (increase/decrease)	-25,410	-240,965
Cash paid for purchase of property and equipment (increase/decrease)	-148,590	-19,412
Net cash (used in) investing activities	-174,000	-194,794
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from sale of common stock (increase/decrease)	2,929,646	816,760
Payments on related party notes payable (increase/decrease)		-32,730
Proceeds from notes payable (increase/decrease)		79,965
Payments on notes payable (increase/decrease)	-110,225	-1,508
Net cash provided by financing activities	2,819,421	862,487
INCREASE IN CASH	139,621	68,382
CASH - BEGINNING BALANCE	69,433	1,051
CASH - ENDING BALANCE	209,054	69,433
Cash paid for interest	$25,448

Note_1_Summary_of_Significant_

Note 1. Summary of Significant Accounting Policies	12 Months Ended
	Oct. 31, 2014
Notes
Note 1. Summary of Significant Accounting Policies	Note 1.  Summary of Significant Accounting Policies
	Organization
	Diversified Resources Inc. (“the Company”) was incorporated in the State of Nevada on March 19, 2009 to pursue mineral extraction in the United States.
	On June 15, 2009 the Company leased two mining claims in Esmerelda County, Nevada, in the Dunfee Mine Area. The lease includes all additional claims within one mile of these claims. The term of the lease was for 20 years and was terminated during November 2013.
	In November 2013, the Company entered into an agreement to exchange securities with Natural Resource Group, Inc. (“NRG”), an oil and gas exploration company, whereby the shareholders of NRG received 14,558,150 shares of the Company’s common stock. In connection with this acquisition, the then President sold 2,680,033 shares of the Company’s common stock to the Company for nominal consideration. The shares purchased from the President were returned to the status of authorized but unissued shares. Additionally, the former principals of the Company assumed all of the debts of the Company at the date of the exchange. The exchange was consummated on November 21, 2013. The transaction was accounted for as a reverse acquisition or recapitalization whereby NRG was considered the accounting acquirer and the Company, the acquire.
	The Company has no interests in any unconsolidated entities, nor does it have any unconsolidated special purpose entities.
	Going Concern
	As shown in the accompanying financial statements, the Company has incurred significant operating losses since inception and has an accumulated deficit of $2,282,333 and has negative working capital of $958,829 at October 31, 2014.  As of October 31, 2014, the Company has limited financial resources.  These factors raise substantial doubt about the Company's ability to continue as a going concern.  The Company's ability to achieve and maintain profitability and positive cash flow is dependent upon its ability to locate profitable mineral properties, generate revenue from planned business operations, and control exploration cost. Management plans to fund its future operations by joint venturing, obtaining additional financing, and attaining additional commercial production. However, there is no assurance that the Company will be able to obtain additional financing from investors or private lenders, or that additional commercial production can be attained.
	The financial statements do not include any adjustments to reflect the possible future effects on the recoverability and classification of assets or the amounts and classification of liabilities that may result from the possible inability of the Company to continue as a going concern.
	Cash and Cash Equivalents
	Cash and cash equivalents include all cash balances and any highly liquid investments with an original maturity of 90 days or less. The carrying amount approximates fair value due to the short maturity of these instruments.
	Accounts Receivable
	The Company records estimated oil and gas revenue receivable from third parties at its net revenue interest. The Company also reflects costs incurred on behalf of joint interest partners in accounts receivable. The Company uses the direct write-off method for bad debts; this method expenses uncollectible accounts in the year they become uncollectible. Any difference between this method and the allowance method is not material. Management periodically reviews accounts receivable amounts for collectability and records its allowance for uncollectible receivables under the direct write-off method. The Company did not record any allowance for uncollectible receivables in 2014 or 2013.
	Use of Estimates
	The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. Estimates of oil and gas reserve quantities provide the basis for calculation of depletion, depreciation, and amortization, and impairment, each of which represents a significant component of the financial statements. Actual results could differ from those estimates.
	Concentration of Credit Risk
	Financial instruments that potentially subject the Company to concentrations of credit risk consist primarily of cash equivalents. The Company places its cash equivalents with a high credit quality financial institution. The Company periodically maintains cash balances at a commercial bank in excess of the Federal Deposit Insurance Corporation insurance limit of $250,000.
	Stock-based compensation
	ASC 718, Stock Compensation requires that all stock-based compensation be recognized as an expense in the financial statements and that such cost be measured at the grant date fair value of the award.
	We record compensation and other charges related to the issuance of stock-based compensation awards at the fair value of the awards. Such awards can be comprised of stock, restricted stock and stock options.
	We record the grant date fair value of stock-based compensation awards as an expense over the vesting period of the related stock options.  In order to determine the fair value of the stock options on the date of grant, we use the Black-Scholes option-pricing model.  Inherent in this model are assumptions related to expected stock-price volatility, option life, risk-free interest rate and dividend yield.  Although the risk-free interest rates and dividend yield are less subjective assumptions, typically based on factual data derived from public sources, the expected stock-price volatility, forfeiture rate and option life assumptions require a greater level of judgment which makes them critical accounting estimates.
	We use an expected stock price volatility assumption that is based on historical volatilities of our common stock and we estimate the forfeiture rate and option life based on historical data related to prior option grants, as we believe such historical data will be similar to future results.
	Dependence on Oil and Gas Prices
	As an independent oil and gas producer, our revenue, profitability and future rate of growth are substantially dependent on prevailing prices for natural gas and oil. Historically, the energy markets have been very volatile, and there can be no assurance that oil and gas prices will not be subject to wide fluctuations in the future. Prices for oil and natural gas have recently declined materially. Any continued and extended decline in oil or gas prices could have a material adverse effect on our financial position, results of operations, cash flows and access to capital and on the quantities of oil and gas reserves that we can economically produce.
	Revenue Recognition
	We recognize oil and gas revenue from interests in producing wells as the oil or gas is sold. Revenue from the purchase, transportation, and sale of natural gas is recognized upon completion of the sale and when transported volumes are delivered. We recognize revenue related to gas balancing agreements based on the sales method. Our net imbalance position at October 31, 2014 and 2013 was immaterial.
	Consulting Fees
	During the year ended October 31, 2013, the Company received consulting fees of $10,347.  The Company provided Colorado land-man and geologic services to an independent entity.  The income was recognized when the services were completed.  All amounts have been collected. No such services were performed in 2014.
	Accounting for Oil and Gas Activities
	Successful Efforts Method   We account for crude oil and natural gas properties under the successful efforts method of accounting. Under this method, costs to acquire mineral interests in crude oil and natural gas properties, drill and equip exploratory wells that find proved reserves, and drill and equip development wells are capitalized. Capitalized costs of producing crude oil and natural gas properties, along with support equipment and facilities, are amortized to expense by the unit-of-production method based on proved crude oil and natural gas reserves on a field-by-field basis, as estimated by our qualified petroleum engineers. Upon sale or retirement of depreciable or depletable property, the cost and related accumulated depreciation, depletion and amortization amounts are eliminated from the accounts and the resulting gain or loss is recognized. Repairs and maintenance are expensed as incurred.
	Assets are grouped in accordance with the Extractive Industries - Oil and Gas Topic of the Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC). The basis for grouping is a reasonable aggregation of properties with a common geological structural feature or stratigraphic condition, such as a reservoir or field.
	Depreciation, depletion and amortization of the cost of proved oil and gas properties are calculated using the unit-of-production method. The reserve base used to calculate depreciation, depletion and amortization for leasehold acquisition costs and the cost to acquire proved properties is the sum of proved developed reserves and proved undeveloped reserves. With respect to lease and well equipment costs, which include development costs and successful exploration drilling costs, the reserve base includes only proved developed reserves. Estimated future dismantlement, restoration and abandonment costs, net of salvage values, are taken into account.
	Proved Property Impairment   We review individually significant proved oil and gas properties and other long-lived assets for impairment at least annually at year-end, or quarterly when events and circumstances indicate a decline in the recoverability of the carrying values of such properties, such as a negative revision of reserves estimates or sustained decrease in commodity prices. We estimate future cash flows expected in connection with the properties and compare such future cash flows to the carrying amount of the properties to determine if the carrying amount is recoverable. When the carrying amount of a property exceeds its estimated undiscounted future cash flows, the carrying amount is reduced to estimated fair value. Fair value may be estimated using comparable market data, a discounted cash flow method, or a combination of the two. In the discounted cash flow method, estimated future cash flows are based on management’s expectations for the future and include estimates of future oil and gas production, commodity prices based on published forward commodity price curves as of the date of the estimate, operating and development costs, and a risk-adjusted discount rate.
	Unproved Property Impairment   Our unproved properties consist of leasehold costs and allocated value to probable and possible reserves from acquisitions. We assess individually significant unproved properties for impairment on a quarterly basis and recognize a loss at the time of impairment by providing an impairment allowance. In determining whether a significant unproved property is impaired we consider numerous factors including, but not limited to, current exploration plans, favorable or unfavorable exploration activity on the property being evaluated and/or adjacent properties, our geologists' evaluation of the property, and the remaining months in the lease term for the property.
	Exploration Costs   Geological and geophysical costs, delay rentals, amortization of unproved leasehold costs, and costs to drill exploratory wells that do not find proved reserves are expensed as oil and gas exploration. We carry the costs of an exploratory well as an asset if the well finds a sufficient quantity of reserves to justify its capitalization as a producing well and as long as we are making sufficient progress assessing the reserves and the economic and operating viability of the project.  Geological and geophysical costs were $41,802 and $69,878 for the years ended October 31, 2014 and 2013, respectively, and are included in Exploration Costs in the accompanying financial statements.
	Asset Retirement Obligations   Asset retirement obligations consist of estimated costs of dismantlement, removal, site reclamation and similar activities associated with our oil and gas properties. We recognize the fair value of a liability for an ARO in the period in which it is incurred when we have an existing legal obligation associated with the retirement of our oil and gas properties that can reasonably be estimated, with the associated asset retirement cost capitalized as part of the carrying cost of the oil and gas asset.  The asset retirement cost is determined at current costs and is inflated into future dollars using an inflation rate that is based on the consumer price index. The future projected cash flows are then discounted to their present value using a credit-adjusted risk-free rate. After initial recording, the liability is increased for the passage of time, with the increase being reflected as accretion expense in the statement of operations. Subsequent adjustments in the cost estimate are reflected in the liability and the amounts continue to be amortized over the useful life of the related long-lived asset.
	Net Income (Loss) per Common Share
	Basic earnings (loss) per share are calculated by dividing net income (loss) by the weighted average number of common shares outstanding for the period. Diluted earnings (loss) per share are calculated by dividing net income (loss) by the weighted average number of common shares and dilutive common stock equivalents outstanding. During the periods when they are anti-dilutive, common stock equivalents, if any, are not considered in the computation.
	Property and Equipment
	Property and equipment consists of production buildings, furniture, fixtures, equipment and vehicles which are recorded at cost and depreciated using the straight-line method over the estimated useful lives of five to fifteen years.
	Maintenance and repairs are charged to expense as incurred.
	Impairment of Long Lived Assets
	The long-lived assets of the Company consist primarily of proved oil and gas properties and undeveloped leaseholds. The Company reviews the carrying values of its oil and gas properties and undeveloped leaseholds annually or whenever events or changes in circumstances indicate that such carrying values may not be recoverable. If, upon review, the sum of the undiscounted pretax cash flows is less than the carrying value of the asset group, the carrying value is written down to estimated fair value. Individual assets are grouped for impairment purposes at the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets, generally on a field-by-field basis. The fair value of impaired assets is determined based on quoted market prices in active markets, if available, or upon the present values of expected future cash flows. The impairment analysis performed by the Company may utilize Level 3 inputs.
	The Company did not record any proved property impairment for the years ended October 31, 2014 and 2013.
	Income Taxes
	We compute income taxes in accordance with ASC Topic 740, Income Taxes.  Under ASC 740, provisions for income taxes are based on taxes payable or refundable during each reporting period and changes in deferred taxes.  Deferred income taxes may arise from temporary differences resulting from income and expense items reported for financial accounting and tax purposes in different periods.   Deferred tax assets and liabilities are included in the financial statements at currently enacted income tax rates applicable to the period in which the deferred tax assets and liabilities are expected to be realized or settled.  Also, the effect on deferred taxes of a change in tax rates is recognized in income in the period that includes the enactment date.  Deferred taxes are classified as current or non-current depending on the classifications of the assets and liabilities to which they relate.   Deferred taxes arising from temporary differences that are not related to an asset or liability are classified as current or non-current depending on the periods in which the temporary differences are expected to reverse.   If available evidence suggests that it is more likely than not that some portion or all of the deferred tax assets will not be realized, a valuation allowance is required to reduce the deferred tax assets to the amount that is more likely than not to be realized.  Future changes in such valuation allowance are included in the provision for deferred income taxes in the period of change.
	We follow the guidance in ASC Topic 740-10, Accounting for Uncertainty in Income Taxes, which prescribes a recognition threshold and a measurement attribute for the financial statement recognition and measurement of tax positions taken or expected to be taken in a tax return.  For those benefits to be recognized, a tax position must be more-likely-than-not to be sustained upon examination by taxing authorities.  The amount recognized is measured as the largest amount of benefit that is greater than 50 percent likely of being realized upon ultimate settlement. The Company does not believe that any material uncertain tax positions exist at October 31, 2014.
	Major Customers
	Sales to major unaffiliated customers consisted of the following, for the year ended October 31, 2014, Customer A accounted for approximately 54% of revenue, Customer B accounted for approximately 17%, Customer C accounted for approximately 13%, and Customer D accounted for approximately 11%.
	Sales to major unaffiliated customers consisted of the following, for the year ended October 31, 2013, Customer A accounted for approximately 30% of revenue, Customer B accounted for approximately 37%, Customer C accounted for approximately 16%, and Customer D accounted for approximately 18%.
	The Company sells production to a small number of customers, as is customary in the industry. Yet, based on the current demand for oil and natural gas, the availability of other buyers, and the Company having the option to sell to other buyers if conditions so warrant, the Company believes that its oil and gas production can be sold in the market in the event that it is not sold to the Company’s existing customers. However, in some circumstances, a change in customers may entail significant transition costs and/or shutting in or curtailing production for weeks or even months during the transition to a new customer.
	Recent Accounting Pronouncements
	There were no recently issued or proposed accounting pronouncements which management believes will have a material effect on the Company’s financial statements.

2_Oil_and_Gas_Properties

2. Oil and Gas Properties	12 Months Ended
	Oct. 31, 2014
Notes
2. Oil and Gas Properties	2.  Oil and gas properties
	Oil and gas properties consist of the following:
		October 31,			October 31,
		2014			2013
	Proved oil and gas properties	$	3,906,215		$	2,661,144
	Proved undeveloped oil and gas leaseholds (Oil and gas properties – proved undeveloped (successful efforts method))		1,209,724			64,126
			5,115,939			2,725,270
	Less accumulated depletion		(100,062	)		(56,726	)
	Net oil and gas properties		5,015,877			2,668,544
	Undeveloped oil and gas leaseholds (Oil and gas properties – unproved (successful efforts method))	$	2,932,730		$	-
	Total depletion of oil and gas properties amounted to $34,475 and $13,800 for the years ended October 31, 2014 and 2013 respectively.

3_Participation_Agreement

3. Participation Agreement	12 Months Ended
	Oct. 31, 2014
Notes
3. Participation Agreement	3.  Participation Agreement
	In connection with the convertible promissory note described in Note 5, the Company entered into a participation agreement with a nonaffiliated company whereby the nonaffiliated company would advance up to $350,000 to conduct additional development of the underlying leases at the Garcia Field and drill and complete three additional wells on the acreage. As of October 31, 2014, $248,895 was due on the note. In consideration for extending this credit arrangement, the lender was assigned a 1% overriding royalty interest in the 4,600 acre field and a 20% modified net profits interest in the existing four producing wells in the Garcia Field and a 20% modified net profits interest in three additional wells to be drilled on said acreage. The Company valued the net profits interest and the overriding royalty interest at $136,599 using 10% present value over the estimated life of the wells. The amount was recorded as a debt discount and is being amortized using the effective interest rate method over the life of the promissory note (3 years). Additionally, the lender has the right, at any point during the period of the note, to convert the remaining principal balance on the note to a working interest (see note 5).
	The modified net profits interest is based on the gross proceeds from the sale of oil, gas and other minerals in the 4 producing wells in the Garcia Field and 3 additional wells to be drilled. The 20% is applied to 100% of the Company’s net revenue interest in the wells which cannot be less than 80% and is reduced by any of the following expenditures:
	any overriding royalties or other burden on production in excess of the 80% net revenue interest;
	production, severance and similar taxes assessed by any taxing authority based on volume or value of the production;
	direct costs incurred in lifting oil or natural gas, or the operating or producing such wells excluding administrative, supervisory or other indirect costs;
	costs reasonably incurred to process the production for market;
	costs reasonably incurred in transportation, delivery, storage or marketing the production.

4_Notes_Payable_Affiliates

4. Notes Payable - Affiliates	12 Months Ended
	Oct. 31, 2014
Notes
4. Notes Payable - Affiliates	4.  Notes Payable - Affiliates
	Notes Payable Affiliates—In December 2010, the Company entered into a purchase and sale agreement to acquire certain oil and gas assets located in Adams, County, Broomfield, County, Huerfano County, Las Animas County, Morgan County and Weld County Colorado. The Company issued 2,500,000 shares of its $0.0001 par value Common Stock and a promissory note for $360,000 bearing interest at 10% with an original maturity date of March 1, 2011. The shares were valued at $1 per share based on sales of our common stock to third-parties. The promissory note is collateralized by the property and equipment transferred and was subsequently subrogated to a convertible promissory note on January 12, 2012 (See Note 5). On July 30, 2013, the maturity date of the note was extended to December 11, 2015.  The balance on the note is $107,070 at October 31, 2014 and 2013, with interest accrued in the amount of $4,579 and $3,872, respectively.

5_Longterm_Debt_and_Note_Payab

5. Long-term Debt and Note Payable	12 Months Ended
	Oct. 31, 2014
Notes
5. Long-term Debt and Note Payable	5.  Long-term Debt and Note Payable
	Convertible Promissory Note—On January 12, 2012 the Company entered into a convertible promissory note bearing interest at 10%, due January 11, 2014 which was extended to July 17, 2015.  The note is collateralized by a first priority deed of trust in approximately 4,600 acres of oil and gas leasehold interests in the Garcia Field, together with the existing wells and equipment in the field. The balance at October 31, 2014 and 2013 was $248,895. The lender has the right to convert the principal to a working interest to a 10% working interest in the collateral as well as a 10% interest in all wells owned by the Company in the Garcia Field in which the lender does not have the 20% modified net profits interest described in Note 3. In the event the principal is less than $350,000, the conversion percentage shall be reduced proportionately. The Company has the right to prepay the note without penalties or fees after giving the lender ten days’ notice of its intent. If lender does elect to convert within 10 days after receiving said notice, the conversion rights terminate.  The Company recorded a discount to the debt of $136,599 and recognized accretion of the discount in the amounts of $19,516 and $75,993 for the years ended October 31, 2014 and 2013 respectively. The ending balance of the debt discount at October 31, 2014 and 2013 was $0 and $19,513, respectively.   The Company reviewed the conversion feature for beneficial conversion features and embedded derivatives and determined that neither applied.
	On October 14, 2014 the Company acquired approximately 98% of the outstanding shares of BIYA Operators, Inc. (“BIYA”) an independent oil and gas company. The Company issued a promissory note in the principal amount of $1,860,000 (subject to adjustment for unknown liabilities).  The note will be effective when certain leases covering Indian tribal lands have been issued.  The note will bear interest at 5% a year and will be payable in October 2016.
	In May 2012 BIYA entered into a settlement agreement with a previous partner in the amount of $1.2 million. The amount is non-interest bearing and has a minimum monthly payment of $10,000, plus one third of BIYA’s net profits, as defined in the agreement, which amounted to approximately $7,000 at October 31, 2014, until paid in full. The balance due was $546,144 at October 31, 2014.
	Convertible Promissory Note—On May 18, 2012 the Company entered into a $70,000 convertible promissory note bearing interest at 10%, the note was paid in full in June 2014.
	Installment Loan—the Company entered into an installment loan on July 4, 2013 bearing interest of 5.39%. The loan is payable in monthly installments of $464 over 48 months commencing August 4, 2013.  The loan is collateralized by a vehicle.
	The following summarizes the notes payable:
		31-Oct-14			31-Oct-13
	Convertible promissory note	$	248,895		$	248,895
	Debt Discount, net of amortization		-			(19,516	)
	BIYA note		1,860,000			-
	BIYA settlement		546,144			-
	Convertible promissory note		-			70,000
	Installment loan		13,750			18,457
			2,668,789			317,836
	Current portion		(373,846	)		(304,071	)
	Long term debt, installment loan	$	2,294,943		$	13,765
	The above debt matures as follows:
		Year ended
		31-Oct
	2015	$	373,846
	2016	$	2,094,424
	2017	$	200,519

6_Asset_Retirement_Obligation

6. Asset Retirement Obligation	12 Months Ended
	Oct. 31, 2014
Notes
6. Asset Retirement Obligation	6.  Asset Retirement Obligation
	The following table reflects a reconciliation of the Company’s asset retirement obligation liability:
		31-Oct-14		31-Oct-13
	Beginning asset retirement obligation	$	222,375	$	203,889
	Liabilities incurred		43,883		-
	Liabilities settled		-		-
	Accretion expense		24,054		20,800
	Revision to estimated cash flows		-		-2,314
	Ending Asset retirement obligation	$	290,312	$	222,375

7_Income_Taxes

7. Income Taxes	12 Months Ended
	Oct. 31, 2014
Notes
7. Income Taxes	7.  Income Taxes
	ASC 740 guidance requires that the Company evaluate all monetary tax positions taken, and recognize a liability for any uncertain tax positions that are not more likely than not to be sustained by the tax authorities. The Company has not recorded any liabilities, or interest and penalties, as of October 31, 2014 related to uncertain tax positions. Deferred tax assets and liabilities are recorded based on the differences between the tax bases of assets and liabilities and their carrying amounts for financial reporting purposes, referred to as temporary differences. Deferred tax assets and liabilities at the end of each period are determined using the currently-enacted tax rates applied to taxable income in the periods in which the deferred tax assets and liabilities are expected to be settled or realized. The provision for income taxes differs from the amount computed by applying the statutory federal income tax rate to income before provision for income taxes. The Company's estimated effective tax rate of 39% is offset by a reserve due to the uncertainty regarding the realization of the deferred tax asset.
	The tax effects of temporary differences that gave rise to the deferred tax liabilities and deferred tax assets as of October 31, 2014 and 2013 were:
		October 31, 2014			October 31, 2013
	Deferred tax assets:
	Net operating loss carry forwards	$	1,422,844		$	747,714
	Deferred tax liability:		-			-
	Property and equipment, geologic  and geophysical		(41,945	)		(41,375	)
			1,380,899			706,339
	Less valuation allowance		(1,380,899	)		(706,339	)
	Deferred tax assets	$	-		$	-
	In assessing the realizability of the deferred tax assets, management considers whether it is more likely than not that some or all of the deferred tax assets will not be realized. The ultimate realization of the deferred tax assets is dependent upon the generation of future taxable income during the periods in which the use of such net operating losses are allowed. Among other items, management considers the scheduled reversal of deferred tax liabilities, tax planning strategies and projected future taxable income. At October 31, 2014, the Company had a net operating loss carry forward for regular income tax reporting purposes of approximately $3.7 million, which will begin expiring in 2030.
	Absent the bargain purchase gain, which is not recognized for income tax purposes, that was recognized at the time of acquisition (see Note 11), the Company would have a loss for both financial statement and tax reporting purposes. Accordingly, and because the Company has fully reserved its deferred income tax assets, no provision and/or benefit for income taxes has been recorded in the accompanying statement of operations.
	The following table shows the reconciliation of the Company’s effective tax rate to the expected federal tax rate for the years ended October 31, 2014 and 2013:
	Statutory U.S. federal rate		34	%
	State income taxes		5	%
			39	%
	Net operating loss		(39	%)
			-	%
	The Company files income tax returns in the U.S. and Colorado jurisdictions. There are currently no federal or state income tax examinations underway for these jurisdictions. Income tax returns since inception are subject to audit by taxing authorities as a result of the net operating loss carryforward.

8_Stockholders_Equity

8. Stockholder's Equity	12 Months Ended
	Oct. 31, 2014
Notes
8. Stockholder's Equity	8.  Stockholder’s Equity
	Common Stock—The Company has 450,000,000 shares of $0.001 par value common stock authorized.
	2013
	The Company issued 395,877 shares of common stock in exchange for settling $65,239 of accounts and notes payable which were valued at their fair value of $395,877 during the year ended October 31, 2013. The difference between the fair value of the shares and the amount of the debt converted of $330,638 was charged to operations during 2013.
	The Company issued 859,750 shares of common stock for cash of $816,760.
	2014
	The Company issued 4,474,089 shares of common stock for cash of $2,929,646.
	The Company issued 900,000 shares of common stock with a fair value of $900,000 for the acquisition of BIYA.
	Included in the shares issued, the Company issued 2,641,052 shares for $2,326,052 to various partners associated with Palo Petroleum, Inc. (“Palo”), 663,720 of these shares for $663,720 were issued in December 2014. On January 29, 2015, the Company entered into a participation agreement with Palo, where Palo acquired right to participate in all future operations in the Horseshoe Gallup Field which are not related to the Existing Wells or Existing Production, including the drilling of any future wells. Palo shall have the right to participate in such future operations as a 40.00% of 8/8 Working Interest owner on a heads-up or non-promoted basis. The Company does not have sufficient information to calculate the value of participation in the future working interest and the future participation cost will be charged to operations earned by Palo.
	In addition, the Company and Palo entered into an Area of Mutual Interest Agreement (“AMI”) consisting of all lands in San Juan County, New Mexico outside the Horseshoe Gallup Field. Under this agreement, Palo and the Company shall each be entitled to participate for up to 50% in any leasehold or fee mineral interest within the AMI which is acquired by either Palo or the Company.

9_Commitments_and_Contingent_L

9. Commitments and Contingent Liabilities	12 Months Ended
	Oct. 31, 2014
Notes
9. Commitments and Contingent Liabilities	9.  Commitments and Contingent Liabilities
	Legal
	We may be subject to legal proceedings, claims and liabilities which arise in the ordinary course of business. We accrue for losses associated with legal claims when such losses are probable and can be reasonably estimated. These accruals are adjusted as additional information becomes available or circumstances change. Legal fees are charged to expense as they are incurred.  The Company is not a party to any material legal proceedings as of February 13, 2015.
	Environmental
	We accrue for losses associated with environmental remediation obligations when such losses are probable and can be reasonably estimated. These accruals are adjusted as additional information becomes available or circumstances change. Costs of future expenditures for environmental remediation obligations are not discounted to their present value. Recoveries of environmental remediation costs from other parties are recorded at their undiscounted value as assets when their receipt is deemed probable. The Company is unaware of any material environmental issues as of February 13, 2015.
	Employment Agreements
	The Company has a written employment agreement with its president. Pursuant to his employment agreement, said officer will devote such time as each deems necessary to perform his duties to the Company and are subject to conflicts of interest. The employment agreement is an “at will agreement;” however, in the event of termination by the Company, the agreement provides for severance pay equal to four months of base salary in effect at the time of termination. There is also a provision providing for twelve months of base pay in the event of a change in control of the Company. The agreement provides for a two year non-compete in the event of termination. Pursuant to the employment agreements, the president will receive a base salary of $150,000 per year.  The president may be granted royalties pursuant to the royalty program.
	The Company has a written “at will” employment agreement with its Operations Manager (also a principal shareholder) which provides for annual compensation of $66,000 and provides that when the Company achieves three consecutive months of positive cash flows to the extent that the Company would still have positive cash flow in the event the compensation was increased by 50%, then there will be a permanent increase in compensation equal to the current compensation multiplied by 150%. In the event of termination by the Company, the agreement provides for severance pay equal to four months of base salary in effect at the time of termination. There is also a provision providing for twelve months of base pay in the event of a change in control of the Company. The agreement provides for a two year non-compete in the event of termination. The Operations Manager may be granted royalties pursuant to the royalty program.
	The Company has no long term lease obligations.

10_Related_Parties

10. Related Parties	12 Months Ended
	Oct. 31, 2014
Notes
10. Related Parties	10.  Related Parties
	The Company executed a lease for office space in Littleton, Colorado, with Spotswood Properties, LLC, a Colorado limited liability company (“Spotswood”), and an affiliate of the president, effective January 1, 2009, for a three-year term. Commencing July 1, 2010 the Company entered into a new lease for the office space for a 3 year period ending July 1, 2013.  The Company is currently leasing the office space on a month to month basis under the same terms and conditions as the lease that expired July 31, 2013. The lease provides for the payment of $2,667 per month plus utilities and other incidentals. The president of the Company owns 50% of Spotswood. The Company is of the opinion that the terms of the lease are no less favorable than could be obtained from an unaffiliated party. Spotswood was paid $26,000 and $32,000 in fiscal years 2014 and 2013, respectively.
	The Company paid $60,642 and $23,822, in fiscal years 2014 and 2013 respectively, to the President’s brother for land-man fees and expense reimbursements in connection with performing contract land services for the Company.
	The Company paid $178,650 and $60,730 to a director for financial public relations consulting in fiscal years 2014 and 2013, respectively.

11_Acquisition

11. Acquisition	12 Months Ended
	Oct. 31, 2014
Notes
11. Acquisition	11.  Acquisition
	On October 14, 2014 the Company acquired approximately 98% of the outstanding shares of BIYA Operators, Inc. (“BIYA”) an independent oil and gas company, for cash of $174,000, 900,000 restricted shares of common stock having a value of $900,000, a promissory note in the principal amount of $1,860,000 (subject to adjustment for unknown liabilities) and the assumption of liabilities of BIYA oil and gas company in the approximate amount of $2,000,000.  The note will be effective when certain leases covering Indian tribal lands have been issued.  The note will bear interest at 5% a year and will be payable in October 2016. The Company did not incur material costs in acquiring BIYA. The transaction was effective October 1, 2014 and was accounted for as a business combination.
	BIYA was incorporated under the laws of New Mexico during on September 2011 to pursue mineral extraction.  BIYA conducts operations in the United States primarily in the Horseshoe Gallop field in San Juan County of New Mexico.
	BIYA’s has oil and gas leases covering approximately 10,100 acres and 48 producing wells. The majority of the leased acreage and producing wells are on Mountain Ute tribal land and are leased under an operating agreement with the tribe, which commenced on April 15, 2008. Under the agreement, BIYA is to drill three wells by April, 2016, two additional wells by April 2017 and April 2018, each. After April 2018, BIYA is required to drill one well per year. Per the agreement, if BIYA drills and completes a well, and establishes production from that well, it will own a lease of that well, plus the applicable well spacing unit acreage surrounding that well, ranging from 40 acres to 320 acres, based on the formation drilled, from the date of filing an application for permit to drill and for as long as hydrocarbons are produced in paying quantities. All leases held by BIYA carry a royalty between 12.5% and 20%.
	The Company has included the results of BIYA’s operations in its consolidated financial statements beginning on October 1, 2014. The following table summarizes the revenue and cost of sales contributed by BIYA:
	Fair values of the assets acquired and liabilities assumed in acquisition of BIYA are summarized below:
	Current assets, including cash and cash equivalents of $98,809	$	242,788
	Property, plant and equipment		1,854,900
	Oil and gas properties		5,244,755
	Bonds and other assets		167,368
	Total assets acquired		7,509,811
	Current liabilities		-1,624,167
	Long-term liabilities		-367,460
	Net assets acquired	$	5,518,184
	Bargain purchase gain		-2,584,184
	Net consideration		2,934,000
	The Consideration consisted of cash of $174,000, the issuance of a note in the amount of $1,860,000, the issuance of 900,000 common shares with a fair value of $900,000.
	The amounts shown above are considered preliminary and are subject to change once the Company receives certain information it believes is necessary to finalize its determination of the fair value of assets acquired and liabilities assumed under the acquisition method. Thus these amounts are subject to refinement, and additional adjustments to record fair value of all assets acquired and liabilities assumed may be required.
	The unaudited results of operations had the acquisition been made at the beginning of the respective years would have been as follows:
		31-Oct-14		31-Oct-13
	Revenues	$	1,583,796	$	2,383,733
	Net income (loss)	$	714,031	$	(1,397,550	)
	Net income (loss) per share	$	0.04	$	(0.10	)

12_Disclosures_About_Oil_and_G

12. Disclosures About Oil and Gas Producing Activities (unaudited)	12 Months Ended
	Oct. 31, 2014
Notes
12. Disclosures About Oil and Gas Producing Activities (unaudited)	12.  Disclosures about Oil and Gas Producing Activities (Unaudited)
	Capitalized costs relating to oil and gas producing activities:
		October 31,		October 31,
		2014		2013
	Proved oil and gas properties	$	3,906,215	$	2,661,144
	Proved undeveloped oil and gas leaseholds (Oil and gas properties – proved undeveloped (successful efforts method))		1,209,724		64,126
			5,115,939		2,725,270
	Less accumulated depletion		-100,062		-56,726
	Net oil and gas properties		5,015,877		2,668,544
	Undeveloped oil and gas leaseholds	$	21,932,730	$	-
	Costs incurred in connection with crude oil and natural gas acquisition, exploration and development are as follows:
		November 1, 2013 to October 31, 2014		November 1, 2012 to October 31, 2013
	Acquisition of properties:
	Proved	$	2,634,245	$	-
	Proved undeveloped		3,251,669		64,126
	Development costs		7,833		176,839
	Exploration costs		41,802		69,878
	Total acquisition of properties	$	5,935,549	$	310,843
	Acquisition cost of proved and proved undeveloped properties acquired in 2014 include properties of BIYA, see Note 11 above for details of the acquisition cost.

13_Results_of_Operations_For_O

13. Results of Operations For Oil and Gas Producing Activities	12 Months Ended
	Oct. 31, 2014
Notes
13. Results of Operations For Oil and Gas Producing Activities	13. Results of Operations for Oil and Gas Producing Activities
	The results of operations for oil and gas producing activities, excluding capital expenditures and corporate overhead and interest costs, are as follows (all in the United States):
		November 1, 2013 to October 31, 2014			November 1, 2012 to October 31, 2013
	Operating Revenues (Oil and gas sales)	$	161,623		$	85,808
	Costs & expenses:
	Exploration costs, including dry holes		41,802			69,878
	Lease operating expenses		290,588			189,212
	Depletion expense		36,066			13,800
	Total costs & expenses		368,456			272,890
	Income (loss) before income taxes		(206,833	)		(187,082	)
	Income tax (expense) benefit		80,665			72,962
	Results of operations for oil and gas producing activities	$	(126,168	)	$	(114,120	)

14_Supplementary_Oil_and_Gas_I

14. Supplementary Oil and Gas Information (unaudited)	12 Months Ended
	Oct. 31, 2014
Notes
14. Supplementary Oil and Gas Information (unaudited)	14.  Supplementary Oil and Gas Information (Unaudited)
	The following supplemental information regarding the oil and gas activities of the Company is presented pursuant to the disclosure requirements promulgated by the Securities and Exchange Commission ("SEC") and FASB ASC 932, Disclosures About Oil and Gas Producing Activities.
	Estimated net quantities of reserves of oil and gas for the years ended October 31, 2014 and 2013:
						Gallons
		Oil (Bbl)		Gas (Mcf)		NG Liquid
	Developed at October 31, 2013		5,379		68,406		-
	Proved undeveloped at October 31, 2013		24,077		620,828		4,678,103
	Balance, October 31, 2013		29,456		689,234		4,678,103
	Developed at October 31, 2014		299,856		51,298		-
	Proved undeveloped at October 31, 2014		1,432,256		1,257,190		6,890,814
	Balance, October 31, 2014		1,732,112		1,308,488		6,890,814
	Notable changes in our reserves are summarized as follows:
	We increased our proved developed reserves by 293,600 Bbls through purchase of BIYA.
	Proved undeveloped reserves increased due to the acquisition of BIYA, which caused an increase in the barrels of oil of 1,408,000. Increase in MCF of 636,362 and gallons of 2,212,711 incurred due to revisions to Garcia field.

15_Standardized_Measure_of_Dis

15. Standardized Measure of Discounted Future Net Cash Flows Relating To Proved Oil and Gas Reserves (unaudited)	12 Months Ended
	Oct. 31, 2014
Notes
15. Standardized Measure of Discounted Future Net Cash Flows Relating To Proved Oil and Gas Reserves (unaudited)	15.  Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves (Unaudited)
	The following is based on natural gas and oil reserves and production volumes estimated by the Company. It may be useful for certain comparison purposes, but should not be solely relied upon in evaluating the Company or its performance. Further, information contained in the following table should not be considered as representative or realistic assessments of future cash flows, nor should the Standardized Measure of Discounted Future Net Cash Flows be viewed as representative of the current value of the Company.
	The Company believes that the following factors should be taken into account in reviewing the following information: (1) future costs and selling prices will likely differ from those required to be used in these calculations; (2) due to future market conditions and governmental regulations, actual rates of production achieved in future years may vary significantly from the rate of production assumed in these calculations; (3) selection of a 10% discount rate, as required under the accounting codification, is arbitrary and may not be reasonable as a measure of the relative risk inherent in realizing future net oil and gas revenues; and (4) future net revenues may be subject to different rates of income taxation.
	Under the Standardized Measure, future cash inflows were estimated by applying the 12-month average pricing of oil and gas relating to the Company’s proved reserves to the year-end quantities of those reserves. Future cash inflows were reduced by estimated future development and production costs based upon year-end costs in order to arrive at net cash flow before tax. Future income tax expense has been computed by applying year-end statutory rates to future pretax net cash flows and the utilization of net operating loss carry-forwards.
	Management does not rely solely upon the following information to make investment and operating decisions. Such decisions are based upon a wide range of factors, including estimates of probable, as well as proved reserves, and varying price and cost assumptions considered more representative of a range of possible economic conditions that may be anticipated.
	Information with respect to the Company’s Standardized Measure is as follows:
		2014			2013
	Future cash inflows	$	158,337,002		$	9,295,085
	Future production costs		(36,046,933	)		(2,987,829	)
	Future development costs		(19,189,499	)		(4,175,000	)
	Future income tax expense		(40,209,222	)		(831,580	)
	Future net cash flows		62,891,348			1,300,676
	10% annual discount for estimated timing of cash flows		(31,944,372	)		(990,662	)
	Standardized measure of discounted future net cash flows	$	30,946,976		$	310,014
	There have been significant fluctuations in the posted prices of oil and natural gas during the last two years. Prices actually received from purchasers of the Company’s oil and gas is adjusted from posted prices for location differentials, quality differentials, and BTU content.
	The following table presents the prices used to prepare the reserve estimates, based upon the unweighted arithmetic average of the first day of the month price for each month within the 12 month period prior to the end of the respective reporting period presented:
		Oil (Bbl)			Gas (Mcf)			NG Liquid
	October 31, 2013 (Average)	$	86.79		$	4.87		$	0.81
	October 31, 2014 (Average)	$	83.96		$	4.37		$	0.99
	Principal changes in the Standardized Measure for the years ended October 31, 2014 and 2013 were as follows:
		2014			2013
	Standardized measure, beginning of year	$	310,014		$	80,397
	Purchase of reserves in place		24,653,719			-
	Purchase of proved undeveloped reserves		118,243,820			725,657
	Sale and transfers, net of production costs		128,965			103,404
	Net changes in prices and production costs		(31,375,014	)		(726,938	)
	Extensions, discoveries, and improved recovery		-			135,610
	Changes in estimated future development costs		(15,014,499	)		(696,875	)
	Development costs incurred during the period		7,833			176,839
	Revision of quantity estimates		4,307,700			110,446
	Accretion of discount		(30,953,709	)		-124,658
	Net change in income taxes		(39,377,642	)		226,504
	Changes in timing and other		15,790			299,628
	Standardized measure, end of year	$	30,946,976		$	310,014

Note_1_Summary_of_Significant_1

Note 1. Summary of Significant Accounting Policies: Organization (Policies)	12 Months Ended
	Oct. 31, 2014
Policies
Organization	Organization
	Diversified Resources Inc. (“the Company”) was incorporated in the State of Nevada on March 19, 2009 to pursue mineral extraction in the United States.
	On June 15, 2009 the Company leased two mining claims in Esmerelda County, Nevada, in the Dunfee Mine Area. The lease includes all additional claims within one mile of these claims. The term of the lease was for 20 years and was terminated during November 2013.
	In November 2013, the Company entered into an agreement to exchange securities with Natural Resource Group, Inc. (“NRG”), an oil and gas exploration company, whereby the shareholders of NRG received 14,558,150 shares of the Company’s common stock. In connection with this acquisition, the then President sold 2,680,033 shares of the Company’s common stock to the Company for nominal consideration. The shares purchased from the President were returned to the status of authorized but unissued shares. Additionally, the former principals of the Company assumed all of the debts of the Company at the date of the exchange. The exchange was consummated on November 21, 2013. The transaction was accounted for as a reverse acquisition or recapitalization whereby NRG was considered the accounting acquirer and the Company, the acquire.
	The Company has no interests in any unconsolidated entities, nor does it have any unconsolidated special purpose entities.

Note_1_Summary_of_Significant_2

Note 1. Summary of Significant Accounting Policies: Going Concern (Policies)	12 Months Ended
	Oct. 31, 2014
Policies
Going Concern	Going Concern
	As shown in the accompanying financial statements, the Company has incurred significant operating losses since inception and has an accumulated deficit of $2,282,333 and has negative working capital of $958,829 at October 31, 2014.  As of October 31, 2014, the Company has limited financial resources.  These factors raise substantial doubt about the Company's ability to continue as a going concern.  The Company's ability to achieve and maintain profitability and positive cash flow is dependent upon its ability to locate profitable mineral properties, generate revenue from planned business operations, and control exploration cost. Management plans to fund its future operations by joint venturing, obtaining additional financing, and attaining additional commercial production. However, there is no assurance that the Company will be able to obtain additional financing from investors or private lenders, or that additional commercial production can be attained.
	The financial statements do not include any adjustments to reflect the possible future effects on the recoverability and classification of assets or the amounts and classification of liabilities that may result from the possible inability of the Company to continue as a going concern.

Note_1_Summary_of_Significant_3

Note 1. Summary of Significant Accounting Policies: Cash and Cash Equivalents (Policies)	12 Months Ended
	Oct. 31, 2014
Policies
Cash and Cash Equivalents	Cash and Cash Equivalents
	Cash and cash equivalents include all cash balances and any highly liquid investments with an original maturity of 90 days or less. The carrying amount approximates fair value due to the short maturity of these instruments.

Note_1_Summary_of_Significant_4

Note 1. Summary of Significant Accounting Policies: Accounts Receivable (Policies)	12 Months Ended
	Oct. 31, 2014
Policies
Accounts Receivable	Accounts Receivable
	The Company records estimated oil and gas revenue receivable from third parties at its net revenue interest. The Company also reflects costs incurred on behalf of joint interest partners in accounts receivable. The Company uses the direct write-off method for bad debts; this method expenses uncollectible accounts in the year they become uncollectible. Any difference between this method and the allowance method is not material. Management periodically reviews accounts receivable amounts for collectability and records its allowance for uncollectible receivables under the direct write-off method. The Company did not record any allowance for uncollectible receivables in 2014 or 2013.

Note_1_Summary_of_Significant_5

Note 1. Summary of Significant Accounting Policies: Use of Estimates (Policies)	12 Months Ended
	Oct. 31, 2014
Policies
Use of Estimates	Use of Estimates
	The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. Estimates of oil and gas reserve quantities provide the basis for calculation of depletion, depreciation, and amortization, and impairment, each of which represents a significant component of the financial statements. Actual results could differ from those estimates.

Note_1_Summary_of_Significant_6

Note 1. Summary of Significant Accounting Policies: Concentration of Credit Risk (Policies)	12 Months Ended
	Oct. 31, 2014
Policies
Concentration of Credit Risk	Concentration of Credit Risk
	Financial instruments that potentially subject the Company to concentrations of credit risk consist primarily of cash equivalents. The Company places its cash equivalents with a high credit quality financial institution. The Company periodically maintains cash balances at a commercial bank in excess of the Federal Deposit Insurance Corporation insurance limit of $250,000.

Note_1_Summary_of_Significant_7

Note 1. Summary of Significant Accounting Policies: Stock-based Compensation (Policies)	12 Months Ended
	Oct. 31, 2014
Policies
Stock-based Compensation	Stock-based compensation
	ASC 718, Stock Compensation requires that all stock-based compensation be recognized as an expense in the financial statements and that such cost be measured at the grant date fair value of the award.
	We record compensation and other charges related to the issuance of stock-based compensation awards at the fair value of the awards. Such awards can be comprised of stock, restricted stock and stock options.
	We record the grant date fair value of stock-based compensation awards as an expense over the vesting period of the related stock options.  In order to determine the fair value of the stock options on the date of grant, we use the Black-Scholes option-pricing model.  Inherent in this model are assumptions related to expected stock-price volatility, option life, risk-free interest rate and dividend yield.  Although the risk-free interest rates and dividend yield are less subjective assumptions, typically based on factual data derived from public sources, the expected stock-price volatility, forfeiture rate and option life assumptions require a greater level of judgment which makes them critical accounting estimates.
	We use an expected stock price volatility assumption that is based on historical volatilities of our common stock and we estimate the forfeiture rate and option life based on historical data related to prior option grants, as we believe such historical data will be similar to future results.

Note_1_Summary_of_Significant_8

Note 1. Summary of Significant Accounting Policies: Dependence On Oil and Gas Prices (Policies)	12 Months Ended
	Oct. 31, 2014
Policies
Dependence On Oil and Gas Prices	Dependence on Oil and Gas Prices
	As an independent oil and gas producer, our revenue, profitability and future rate of growth are substantially dependent on prevailing prices for natural gas and oil. Historically, the energy markets have been very volatile, and there can be no assurance that oil and gas prices will not be subject to wide fluctuations in the future. Prices for oil and natural gas have recently declined materially. Any continued and extended decline in oil or gas prices could have a material adverse effect on our financial position, results of operations, cash flows and access to capital and on the quantities of oil and gas reserves that we can economically produce.

Note_1_Summary_of_Significant_9

Note 1. Summary of Significant Accounting Policies: Revenue Recognition (Policies)	12 Months Ended
	Oct. 31, 2014
Policies
Revenue Recognition	Revenue Recognition
	We recognize oil and gas revenue from interests in producing wells as the oil or gas is sold. Revenue from the purchase, transportation, and sale of natural gas is recognized upon completion of the sale and when transported volumes are delivered. We recognize revenue related to gas balancing agreements based on the sales method. Our net imbalance position at October 31, 2014 and 2013 was immaterial.

Recovered_Sheet1

Note 1. Summary of Significant Accounting Policies: Consulting Fees (Policies)	12 Months Ended
	Oct. 31, 2014
Policies
Consulting Fees	Consulting Fees
	During the year ended October 31, 2013, the Company received consulting fees of $10,347.  The Company provided Colorado land-man and geologic services to an independent entity.  The income was recognized when the services were completed.  All amounts have been collected. No such services were performed in 2014.

Recovered_Sheet2

Note 1. Summary of Significant Accounting Policies: Accounting For Oil and Gas Activities (Policies)	12 Months Ended
	Oct. 31, 2014
Policies
Accounting For Oil and Gas Activities	Accounting for Oil and Gas Activities
	Successful Efforts Method   We account for crude oil and natural gas properties under the successful efforts method of accounting. Under this method, costs to acquire mineral interests in crude oil and natural gas properties, drill and equip exploratory wells that find proved reserves, and drill and equip development wells are capitalized. Capitalized costs of producing crude oil and natural gas properties, along with support equipment and facilities, are amortized to expense by the unit-of-production method based on proved crude oil and natural gas reserves on a field-by-field basis, as estimated by our qualified petroleum engineers. Upon sale or retirement of depreciable or depletable property, the cost and related accumulated depreciation, depletion and amortization amounts are eliminated from the accounts and the resulting gain or loss is recognized. Repairs and maintenance are expensed as incurred.
	Assets are grouped in accordance with the Extractive Industries - Oil and Gas Topic of the Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC). The basis for grouping is a reasonable aggregation of properties with a common geological structural feature or stratigraphic condition, such as a reservoir or field.
	Depreciation, depletion and amortization of the cost of proved oil and gas properties are calculated using the unit-of-production method. The reserve base used to calculate depreciation, depletion and amortization for leasehold acquisition costs and the cost to acquire proved properties is the sum of proved developed reserves and proved undeveloped reserves. With respect to lease and well equipment costs, which include development costs and successful exploration drilling costs, the reserve base includes only proved developed reserves. Estimated future dismantlement, restoration and abandonment costs, net of salvage values, are taken into account.
	Proved Property Impairment   We review individually significant proved oil and gas properties and other long-lived assets for impairment at least annually at year-end, or quarterly when events and circumstances indicate a decline in the recoverability of the carrying values of such properties, such as a negative revision of reserves estimates or sustained decrease in commodity prices. We estimate future cash flows expected in connection with the properties and compare such future cash flows to the carrying amount of the properties to determine if the carrying amount is recoverable. When the carrying amount of a property exceeds its estimated undiscounted future cash flows, the carrying amount is reduced to estimated fair value. Fair value may be estimated using comparable market data, a discounted cash flow method, or a combination of the two. In the discounted cash flow method, estimated future cash flows are based on management’s expectations for the future and include estimates of future oil and gas production, commodity prices based on published forward commodity price curves as of the date of the estimate, operating and development costs, and a risk-adjusted discount rate.
	Unproved Property Impairment   Our unproved properties consist of leasehold costs and allocated value to probable and possible reserves from acquisitions. We assess individually significant unproved properties for impairment on a quarterly basis and recognize a loss at the time of impairment by providing an impairment allowance. In determining whether a significant unproved property is impaired we consider numerous factors including, but not limited to, current exploration plans, favorable or unfavorable exploration activity on the property being evaluated and/or adjacent properties, our geologists' evaluation of the property, and the remaining months in the lease term for the property.
	Exploration Costs   Geological and geophysical costs, delay rentals, amortization of unproved leasehold costs, and costs to drill exploratory wells that do not find proved reserves are expensed as oil and gas exploration. We carry the costs of an exploratory well as an asset if the well finds a sufficient quantity of reserves to justify its capitalization as a producing well and as long as we are making sufficient progress assessing the reserves and the economic and operating viability of the project.  Geological and geophysical costs were $41,802 and $69,878 for the years ended October 31, 2014 and 2013, respectively, and are included in Exploration Costs in the accompanying financial statements.
	Asset Retirement Obligations   Asset retirement obligations consist of estimated costs of dismantlement, removal, site reclamation and similar activities associated with our oil and gas properties. We recognize the fair value of a liability for an ARO in the period in which it is incurred when we have an existing legal obligation associated with the retirement of our oil and gas properties that can reasonably be estimated, with the associated asset retirement cost capitalized as part of the carrying cost of the oil and gas asset.  The asset retirement cost is determined at current costs and is inflated into future dollars using an inflation rate that is based on the consumer price index. The future projected cash flows are then discounted to their present value using a credit-adjusted risk-free rate. After initial recording, the liability is increased for the passage of time, with the increase being reflected as accretion expense in the statement of operations. Subsequent adjustments in the cost estimate are reflected in the liability and the amounts continue to be amortized over the useful life of the related long-lived asset.

Recovered_Sheet3

Note 1. Summary of Significant Accounting Policies: Net Income (loss) Per Common Share (Policies)	12 Months Ended
	Oct. 31, 2014
Policies
Net Income (loss) Per Common Share	Net Income (Loss) per Common Share
	Basic earnings (loss) per share are calculated by dividing net income (loss) by the weighted average number of common shares outstanding for the period. Diluted earnings (loss) per share are calculated by dividing net income (loss) by the weighted average number of common shares and dilutive common stock equivalents outstanding. During the periods when they are anti-dilutive, common stock equivalents, if any, are not considered in the computation.

Recovered_Sheet4

Note 1. Summary of Significant Accounting Policies: Property and Equipment (Policies)	12 Months Ended
	Oct. 31, 2014
Policies
Property and Equipment	Property and Equipment
	Property and equipment consists of production buildings, furniture, fixtures, equipment and vehicles which are recorded at cost and depreciated using the straight-line method over the estimated useful lives of five to fifteen years.
	Maintenance and repairs are charged to expense as incurred.

Recovered_Sheet5

Note 1. Summary of Significant Accounting Policies: Impairment of Long Lived Assets (Policies)	12 Months Ended
	Oct. 31, 2014
Policies
Impairment of Long Lived Assets	Impairment of Long Lived Assets
	The long-lived assets of the Company consist primarily of proved oil and gas properties and undeveloped leaseholds. The Company reviews the carrying values of its oil and gas properties and undeveloped leaseholds annually or whenever events or changes in circumstances indicate that such carrying values may not be recoverable. If, upon review, the sum of the undiscounted pretax cash flows is less than the carrying value of the asset group, the carrying value is written down to estimated fair value. Individual assets are grouped for impairment purposes at the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets, generally on a field-by-field basis. The fair value of impaired assets is determined based on quoted market prices in active markets, if available, or upon the present values of expected future cash flows. The impairment analysis performed by the Company may utilize Level 3 inputs.
	The Company did not record any proved property impairment for the years ended October 31, 2014 and 2013.

Recovered_Sheet6

Note 1. Summary of Significant Accounting Policies: Income Taxes (Policies)	12 Months Ended
	Oct. 31, 2014
Policies
Income Taxes	Income Taxes
	We compute income taxes in accordance with ASC Topic 740, Income Taxes.  Under ASC 740, provisions for income taxes are based on taxes payable or refundable during each reporting period and changes in deferred taxes.  Deferred income taxes may arise from temporary differences resulting from income and expense items reported for financial accounting and tax purposes in different periods.   Deferred tax assets and liabilities are included in the financial statements at currently enacted income tax rates applicable to the period in which the deferred tax assets and liabilities are expected to be realized or settled.  Also, the effect on deferred taxes of a change in tax rates is recognized in income in the period that includes the enactment date.  Deferred taxes are classified as current or non-current depending on the classifications of the assets and liabilities to which they relate.   Deferred taxes arising from temporary differences that are not related to an asset or liability are classified as current or non-current depending on the periods in which the temporary differences are expected to reverse.   If available evidence suggests that it is more likely than not that some portion or all of the deferred tax assets will not be realized, a valuation allowance is required to reduce the deferred tax assets to the amount that is more likely than not to be realized.  Future changes in such valuation allowance are included in the provision for deferred income taxes in the period of change.
	We follow the guidance in ASC Topic 740-10, Accounting for Uncertainty in Income Taxes, which prescribes a recognition threshold and a measurement attribute for the financial statement recognition and measurement of tax positions taken or expected to be taken in a tax return.  For those benefits to be recognized, a tax position must be more-likely-than-not to be sustained upon examination by taxing authorities.  The amount recognized is measured as the largest amount of benefit that is greater than 50 percent likely of being realized upon ultimate settlement. The Company does not believe that any material uncertain tax positions exist at October 31, 2014.

Recovered_Sheet7

Note 1. Summary of Significant Accounting Policies: Major Customers (Policies)	12 Months Ended
	Oct. 31, 2014
Policies
Major Customers	Major Customers
	Sales to major unaffiliated customers consisted of the following, for the year ended October 31, 2014, Customer A accounted for approximately 54% of revenue, Customer B accounted for approximately 17%, Customer C accounted for approximately 13%, and Customer D accounted for approximately 11%.
	Sales to major unaffiliated customers consisted of the following, for the year ended October 31, 2013, Customer A accounted for approximately 30% of revenue, Customer B accounted for approximately 37%, Customer C accounted for approximately 16%, and Customer D accounted for approximately 18%.
	The Company sells production to a small number of customers, as is customary in the industry. Yet, based on the current demand for oil and natural gas, the availability of other buyers, and the Company having the option to sell to other buyers if conditions so warrant, the Company believes that its oil and gas production can be sold in the market in the event that it is not sold to the Company’s existing customers. However, in some circumstances, a change in customers may entail significant transition costs and/or shutting in or curtailing production for weeks or even months during the transition to a new customer.

Recovered_Sheet8

Note 1. Summary of Significant Accounting Policies: Recent Accounting Pronouncements (Policies)	12 Months Ended
	Oct. 31, 2014
Policies
Recent Accounting Pronouncements	Recent Accounting Pronouncements
	There were no recently issued or proposed accounting pronouncements which management believes will have a material effect on the Company’s financial statements.

2_Oil_and_Gas_Properties_Prope

2. Oil and Gas Properties: Property, Plant and Equipment (Tables)	12 Months Ended
	Oct. 31, 2014
Tables/Schedules
Property, Plant and Equipment
		October 31,			October 31,
		2014			2013
	Proved oil and gas properties	$	3,906,215		$	2,661,144
	Proved undeveloped oil and gas leaseholds (Oil and gas properties – proved undeveloped (successful efforts method))		1,209,724			64,126
			5,115,939			2,725,270
	Less accumulated depletion		(100,062	)		(56,726	)
	Net oil and gas properties		5,015,877			2,668,544
	Undeveloped oil and gas leaseholds (Oil and gas properties – unproved (successful efforts method))	$	2,932,730		$	-

5_Longterm_Debt_and_Note_Payab1

5. Long-term Debt and Note Payable: Schedule of Debt (Tables)	12 Months Ended
	Oct. 31, 2014
Tables/Schedules
Schedule of Debt
		31-Oct-14			31-Oct-13
	Convertible promissory note	$	248,895		$	248,895
	Debt Discount, net of amortization		-			(19,516	)
	BIYA note		1,860,000			-
	BIYA settlement		546,144			-
	Convertible promissory note		-			70,000
	Installment loan		13,750			18,457
			2,668,789			317,836
	Current portion		(373,846	)		(304,071	)
	Long term debt, installment loan	$	2,294,943		$	13,765

5_Longterm_Debt_and_Note_Payab2

5. Long-term Debt and Note Payable: Schedule of Maturities of Long-term Debt (Tables)	12 Months Ended
	Oct. 31, 2014
Tables/Schedules
Schedule of Maturities of Long-term Debt
		Year ended
		31-Oct
	2015	$	373,846
	2016	$	2,094,424
	2017	$	200,519

6_Asset_Retirement_Obligation_

6. Asset Retirement Obligation: Schedule of Asset Retirement Obligations (Tables)	12 Months Ended
	Oct. 31, 2014
Tables/Schedules
Schedule of Asset Retirement Obligations
		31-Oct-14		31-Oct-13
	Beginning asset retirement obligation	$	222,375	$	203,889
	Liabilities incurred		43,883		-
	Liabilities settled		-		-
	Accretion expense		24,054		20,800
	Revision to estimated cash flows		-		-2,314
	Ending Asset retirement obligation	$	290,312	$	222,375

7_Income_Taxes_Schedule_of_Def

7. Income Taxes: Schedule of Deferred Tax Assets and Liabilities (Tables)	12 Months Ended
	Oct. 31, 2014
Tables/Schedules
Schedule of Deferred Tax Assets and Liabilities
		October 31, 2014			October 31, 2013
	Deferred tax assets:
	Net operating loss carry forwards	$	1,422,844		$	747,714
	Deferred tax liability:		-			-
	Property and equipment, geologic  and geophysical		(41,945	)		(41,375	)
			1,380,899			706,339
	Less valuation allowance		(1,380,899	)		(706,339	)
	Deferred tax assets	$	-		$	-

7_Income_Taxes_Schedule_of_Eff

7. Income Taxes: Schedule of Effective Income Tax Rate Reconciliation (Tables)	12 Months Ended
	Oct. 31, 2014
Tables/Schedules
Schedule of Effective Income Tax Rate Reconciliation
	Statutory U.S. federal rate	34	%
	State income taxes	5	%
		39	%
	Net operating loss	(39	%)
		-	%

11_Acquisition_Schedule_of_Fai

11. Acquisition: Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis (Tables)	12 Months Ended
	Oct. 31, 2014
Tables/Schedules
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis
	Current assets, including cash and cash equivalents of $98,809	$	242,788
	Property, plant and equipment		1,854,900
	Oil and gas properties		5,244,755
	Bonds and other assets		167,368
	Total assets acquired		7,509,811
	Current liabilities		-1,624,167
	Long-term liabilities		-367,460
	Net assets acquired	$	5,518,184
	Bargain purchase gain		-2,584,184
	Net consideration		2,934,000

11_Acquisition_Fair_Value_Asse

11. Acquisition: Fair Value, Assets and Liabilities Measured on Nonrecurring Basis, Valuation Techniques (Tables)	12 Months Ended
	Oct. 31, 2014
Tables/Schedules
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis, Valuation Techniques
		31-Oct-14		31-Oct-13
	Revenues	$	1,583,796	$	2,383,733
	Net income (loss)	$	714,031	$	(1,397,550	)
	Net income (loss) per share	$	0.04	$	(0.10	)

12_Disclosures_About_Oil_and_G1

12. Disclosures About Oil and Gas Producing Activities (unaudited): Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure (Tables)	12 Months Ended
	Oct. 31, 2014
Tables/Schedules
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure
		October 31,		October 31,
		2014		2013
	Proved oil and gas properties	$	3,906,215	$	2,661,144
	Proved undeveloped oil and gas leaseholds (Oil and gas properties – proved undeveloped (successful efforts method))		1,209,724		64,126
			5,115,939		2,725,270
	Less accumulated depletion		-100,062		-56,726
	Net oil and gas properties		5,015,877		2,668,544
	Undeveloped oil and gas leaseholds	$	21,932,730	$	-

12_Disclosures_About_Oil_and_G2

12. Disclosures About Oil and Gas Producing Activities (unaudited): Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure (Tables)	12 Months Ended
	Oct. 31, 2014
Tables/Schedules
Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure
		November 1, 2013 to October 31, 2014		November 1, 2012 to October 31, 2013
	Acquisition of properties:
	Proved	$	2,634,245	$	-
	Proved undeveloped		3,251,669		64,126
	Development costs		7,833		176,839
	Exploration costs		41,802		69,878
	Total acquisition of properties	$	5,935,549	$	310,843

13_Results_of_Operations_For_O1

13. Results of Operations For Oil and Gas Producing Activities: Schedule of Oil and Gas In Process Activities (Tables)	12 Months Ended
	Oct. 31, 2014
Tables/Schedules
Schedule of Oil and Gas In Process Activities
		November 1, 2013 to October 31, 2014			November 1, 2012 to October 31, 2013
	Operating Revenues (Oil and gas sales)	$	161,623		$	85,808
	Costs & expenses:
	Exploration costs, including dry holes		41,802			69,878
	Lease operating expenses		290,588			189,212
	Depletion expense		36,066			13,800
	Total costs & expenses		368,456			272,890
	Income (loss) before income taxes		(206,833	)		(187,082	)
	Income tax (expense) benefit		80,665			72,962
	Results of operations for oil and gas producing activities	$	(126,168	)	$	(114,120	)

14_Supplementary_Oil_and_Gas_I1

14. Supplementary Oil and Gas Information (unaudited): Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities (Tables)	12 Months Ended
	Oct. 31, 2014
Tables/Schedules
Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities
						Gallons
		Oil (Bbl)		Gas (Mcf)		NG Liquid
	Developed at October 31, 2013		5,379		68,406		-
	Proved undeveloped at October 31, 2013		24,077		620,828		4,678,103
	Balance, October 31, 2013		29,456		689,234		4,678,103
	Developed at October 31, 2014		299,856		51,298		-
	Proved undeveloped at October 31, 2014		1,432,256		1,257,190		6,890,814
	Balance, October 31, 2014		1,732,112		1,308,488		6,890,814

15_Standardized_Measure_of_Dis1

15. Standardized Measure of Discounted Future Net Cash Flows Relating To Proved Oil and Gas Reserves (unaudited): Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure (Tables)	12 Months Ended
	Oct. 31, 2014
Tables/Schedules
Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure
		2014			2013
	Future cash inflows	$	158,337,002		$	9,295,085
	Future production costs		(36,046,933	)		(2,987,829	)
	Future development costs		(19,189,499	)		(4,175,000	)
	Future income tax expense		(40,209,222	)		(831,580	)
	Future net cash flows		62,891,348			1,300,676
	10% annual discount for estimated timing of cash flows		(31,944,372	)		(990,662	)
	Standardized measure of discounted future net cash flows	$	30,946,976		$	310,014

15_Standardized_Measure_of_Dis2

15. Standardized Measure of Discounted Future Net Cash Flows Relating To Proved Oil and Gas Reserves (unaudited): Oil and Gas Net Production, Average Sales Price and Average Production Costs Disclosure (Tables)	12 Months Ended
	Oct. 31, 2014
Tables/Schedules
Oil and Gas Net Production, Average Sales Price and Average Production Costs Disclosure
		Oil (Bbl)		Gas (Mcf)		NG Liquid
	October 31, 2013 (Average)	$	86.79	$	4.87	$	0.81
	October 31, 2014 (Average)	$	83.96	$	4.37	$	0.99

15_Standardized_Measure_of_Dis3

15. Standardized Measure of Discounted Future Net Cash Flows Relating To Proved Oil and Gas Reserves (unaudited): Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows (Tables)	12 Months Ended
	Oct. 31, 2014
Tables/Schedules
Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows
		2014			2013
	Standardized measure, beginning of year	$	310,014		$	80,397
	Purchase of reserves in place		24,653,719			-
	Purchase of proved undeveloped reserves		118,243,820			725,657
	Sale and transfers, net of production costs		128,965			103,404
	Net changes in prices and production costs		(31,375,014	)		(726,938	)
	Extensions, discoveries, and improved recovery		-			135,610
	Changes in estimated future development costs		(15,014,499	)		(696,875	)
	Development costs incurred during the period		7,833			176,839
	Revision of quantity estimates		4,307,700			110,446
	Accretion of discount		(30,953,709	)		-124,658
	Net change in income taxes		(39,377,642	)		226,504
	Changes in timing and other		15,790			299,628
	Standardized measure, end of year	$	30,946,976		$	310,014

Recovered_Sheet9

Note 1. Summary of Significant Accounting Policies: Going Concern (Details) (USD $)	Oct. 31, 2014	Oct. 31, 2013
Details
Accumulated deficit	$2,282,333	$3,008,453
Capital	$958,829

Recovered_Sheet10

Note 1. Summary of Significant Accounting Policies: Consulting Fees (Details) (USD $)	12 Months Ended
	Oct. 31, 2013
Details
Consulting fees	$10,347

Recovered_Sheet11

Note 1. Summary of Significant Accounting Policies: Accounting For Oil and Gas Activities (Details) (USD $)	12 Months Ended
	Oct. 31, 2014	Oct. 31, 2013
Details
Exploration costs, including dry holes	$41,802	$69,878

2_Oil_and_Gas_Properties_Prope1

2. Oil and Gas Properties: Property, Plant and Equipment (Details) (USD $)	Oct. 31, 2014	Oct. 31, 2013
Details
Oil and Gas Property, Successful Effort Method, Gross	$3,906,215	$2,661,144
Oil and gas properties - proved undeveloped (successful efforts method)	1,209,724	64,126
Oil and Gas Property, Successful Effort Method, Accumulated Depreciation, Depletion and Amortization	-100,062	-56,726
Oil and gas properties - unproved (successful efforts method)	$2,932,730

2_Oil_and_Gas_Properties_Detai

2. Oil and Gas Properties (Details) (USD $)	12 Months Ended
	Oct. 31, 2014	Oct. 31, 2013
Details
Depletion expense	$34,475	$13,800

3_Participation_Agreement_Deta

3. Participation Agreement (Details) (USD $)	Oct. 31, 2014	Oct. 31, 2013
Details
Notes Payable, Current	$248,895	$248,895

4_Notes_Payable_Affiliates_Det

4. Notes Payable - Affiliates (Details) (USD $)	Oct. 31, 2014	Oct. 31, 2013
Details
Other Notes Payable, Current	$107,070
Accrued interest, related party	$4,579	$3,872

5_Longterm_Debt_and_Note_Payab3

5. Long-term Debt and Note Payable (Details) (USD $)	12 Months Ended
	Oct. 31, 2014	Oct. 31, 2013
Details
Notes Payable, Current	$248,895	$248,895
Accretion of Discount	19,516	75,993
Debt Instrument, Unamortized Discount	0	19,513
Notes Payable	$546,144

5_Longterm_Debt_and_Note_Payab4

5. Long-term Debt and Note Payable: Schedule of Debt (Details) (USD $)	Oct. 31, 2014	Oct. 31, 2013
Details
Notes Payable, Current	$248,895	$248,895
Long term debt, installment loan	$2,294,943	$13,765

6_Asset_Retirement_Obligation_1

6. Asset Retirement Obligation: Schedule of Asset Retirement Obligations (Details) (USD $)	Oct. 31, 2014	Oct. 31, 2013
Details
Asset retirement obligation	$290,312	$222,375

7_Income_Taxes_Schedule_of_Def1

7. Income Taxes: Schedule of Deferred Tax Assets and Liabilities (Details) (USD $)	Oct. 31, 2014	Oct. 31, 2013
Details
Deferred Tax Assets, Operating Loss Carryforwards	$1,422,844	$747,714
Deferred Tax Assets, Net	-41,945	-41,375
Deferred Tax Assets, Valuation Allowance	($1,380,899)	($706,339)

8_Stockholders_Equity_Details

8. Stockholder's Equity (Details) (USD $)	12 Months Ended
	Oct. 31, 2014	Oct. 31, 2013
Details
Common Stock, Shares Authorized	450,000,000	450,000,000
Common Stock, Par Value	$0.00	$0.00
Conversion of debt to common stock, Shares		395,877
Common stock issued for cash, Shares	4,474,089	859,750

10_Related_Parties_Details

10. Related Parties (Details) (USD $)	12 Months Ended
	Oct. 31, 2014	Oct. 31, 2013
Details
Operating Leases, Rent Expense	$26,000	$32,000
Exploration Expense	60,642	23,822
Marketing and Advertising Expense	$178,650	$60,730

12_Disclosures_About_Oil_and_G3

12. Disclosures About Oil and Gas Producing Activities (unaudited): Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure (Details) (USD $)	Oct. 31, 2014	Oct. 31, 2013
Details
Oil and gas properties - proved undeveloped (successful efforts method)	$1,209,724	$64,126
Mineral Properties, Accumulated Depletion	($100,062)	($56,726)

12_Disclosures_About_Oil_and_G4

12. Disclosures About Oil and Gas Producing Activities (unaudited): Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure (Details) (USD $)	12 Months Ended
	Oct. 31, 2014	Oct. 31, 2013
Details
Costs Incurred, Acquisition of Oil and Gas Properties	$5,935,549	$310,843

13_Results_of_Operations_For_O2

13. Results of Operations For Oil and Gas Producing Activities: Schedule of Oil and Gas In Process Activities (Details) (USD $)	12 Months Ended
	Oct. 31, 2014	Oct. 31, 2013
Details
Oil and gas sales	$161,623	$85,808
Exploration costs, including dry holes	41,802	69,878
Lease operating expenses	290,588	189,212
Depletion of Oil and Gas Properties	36,066	13,800
Costs and Expenses	368,456	272,890
Results of Operations, Revenue from Oil and Gas Producing Activities	($126,168)	($114,120)