UNITED STATES


SECURITIES AND EXCHANGE COMMISSION


Washington, D.C. 20549





FORM 10-Q





x Quarterly Report Pursuant To Section 13 or 15(D) Of The Securities Exchange Act Of 1934





For the quarterly period ended April 30, 2014





o Transition Report Under Section 13 Or 15(D) Of The Securities Exchange Act Of 1934





For the transition period from _______________ to _______________





COMMISSION FILE NUMBER    333-175183





DIVERSIFIED RESOURCES INC.


(Exact name of registrant as specified in its charter)





NEVADA
98-0687026(State or other jurisdiction of

incorporation or organization)
(I.R.S. Employer

Identification No.)





1789 W. Littleton Blvd., Littleton, CO 80120


(Address of principal executive offices, including zip code)





303-797-5417


(Issuer’s telephone number, including area code)








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





Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes xNo o





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





Large accelerated filer
o
Accelerated filer
oNon-accelerated filer
o
Smaller reporting company
x





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





State the number of shares outstanding of each of the issuer’s classes of common equity, as of the latest practicable date. 18,565,867 shares of common stock as of June 2, 2014.






1
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DIVERSIFED RESOURCES, INC.





Index





PagePart I – FINANCIAL INFORMATION
3Item 1.
Financial Statements
3Balance Sheets as of April 30, 2014 (unaudited)and October 31, 2013
3Statements of Operations for the three months endedApril 30, 2014 and April 30, 2013 (unaudited)
4Statements of Operations for the six months endedApril 31, 2014 and April 31, 2013 (unaudited
5Statements of Cash Flows for the six months endedApril 30, 2014 and April 30, 2013  (unaudited)
6Notes to Financial Statements (unaudited)
7 - 13Item 2.
Management's Discussion and Analysis of Financial Condition and Results of Operations
14Item 3.
Quantitative and Qualitative Disclosures About Market Risk
20Item 4.
Controls and Procedures
20Part II – OTHER INFORMATION
20Item 2.
Unregistered Sales of Equity Securities and Use of Proceeds
20Item 6.
Exhibits
20SIGNATURES
21















2
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PART I
  ITEM 1.  FINANCIAL STATEMENTS




Diversified Resources, Inc.CONSOLIDATED BALANCE SHEETSApril 30,


October 31,2014


2013(Unaudited)ASSETSCURRENT ASSETSCash

$
113,021


$
69,433Accounts receivable, trade


6,411



32,378Prepaid expenses


16,286



8,870Total current assets


135,718



110,681LONG-LIVED ASSETSProperty and Equipment, net of accumulated depreciationof $8,342 and $4,111 in 2014 and 2013 respectively


36,439



39,392Oil and gas properties - proved (successful efforts method)net of accumulated depletion of $63,995 and $56,726 in 2014 and 2013 respectively


2,597,217



2,604,418Oil and gas properties - proved undeveloped (successful efforts method)


64,126



64,126Total assets

$
2,833,500


$
2,818,617LIABILITIES AND STOCKHOLDERS' EQUITYCURRENT LIABILITIESAccounts payable

$
168,517


$
185,251Accounts payable, related party


127,736



130,361Current portion of long term debt


4,692



4,692Notes payable


318,895



299,379Accrued interest


2,165



2,411Accrued interest, related party


9,226



3,872Accrued expenses


115,974



109,193Total current liabilities


747,205



735,159LONG TERM LIABILITIESLong term debt, related party


107,070



107,070Long term debt


11,451



13,765Asset retirement obligation


226,375



222,375COMMITMENTS AND CONTINGENT LIABILITIESSTOCKHOLDERS' EQUITYPreferred stock, $0.001 par value  50,000,000 shares authorized:none issued and outstanding


-



-Common stock, $0.001 par value, 450,000,000 shares authorized,18,445,867 and  14,563,150 shares issued and outstanding in 2014 and 2013 respectively


18,446



14,563Additional paid in capital


5,447,266



4,734,138Accumulated deficit


(3,724,313
)


(3,008,453
)Total stockholders' equity


1,741,399



1,740,248Total liabilities and stockholders' equity

$
2,833,500


$
2,818,617


See accompanying notes to the financial statements.




3
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Diversified Resources, Inc.CONSOLIDATED STATEMENTS OF OPERATIONS(Unaudited)Three Months EndedApril 30,


April 30,2014


2013Operating revenuesOil and gas sales

$
9,874


$
11,481Operating expensesExploration costs, including dry holes


19,984



16,500Lease operating expenses


66,372



30,086General and administrative


309,124



65,253Depreciation expense


3,679



1,035Depletion expense


1,800



3,000Accretion expense


2,000



5,200Total operating expenses


402,959



121,074(Loss) from operations


(393,085
)


(109,593
)Other income (expense)Interest expense


(13,070
)


(30,821
)Other income (expense), net


(13,070
)


(30,821
)Net (loss)

$
(406,155
)

$
(140,414
)Net (loss) per common shareBasic and diluted

$
(0.02
)

$
(0.01
)Weighted average shares outstandingBasic and diluted


17,704,826



13,095,085


See accompanying notes to the financial statements.




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Diversified Resources, Inc.CONSOLIDATED STATEMENTS OF OPERATIONS(Unaudited)Six Months EndedApril 30,


April 30,2014


2013Operating revenuesOil and gas sales

$
22,640


$
32,113Operating expensesExploration costs, including dry holes


41,801



33,020Lease operating expenses


122,018



36,530General and administrative


515,622



115,100Depreciation expense


7,358



1,968Depletion expense


4,100



7,400Accretion expense


4,000



10,400Total operating expenses


694,899



204,418(Loss) from operations


(672,259
)


(172,305
)Other income (expense)Loss on disposition of assets


-



(34,480
)Interest expense


(43,601
)


(60,067
)Other income (expense), net


(43,601
)


(94,547
)Net (loss)


(715,860
)


(266,852
)Net (loss) per common shareBasic and diluted

$
(0.04
)

$
(0.02
)Weighted average shares outstandingBasic and diluted


17,197,260



13,095,085












See accompanying notes to the financial statements.




5
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Diversified Resources, Inc.CONSOLIDATED  STATEMENTS OF CASH FLOWS(Unaudited)Six Months EndedApril 30,


April 30,2014


2013CASH FLOWS FROM OPERATING ACTIVITIES:Net cash (used in) operating activities

$
(669,820
)

$
(78,294
)CASH FLOWS FROM INVESTING ACTIVITIES:Cash paid for oil and gas properties


-



(4,140
)Cash paid for purchase of property and equipment


(1,278
)


(2,209
)Net cash (used in) investing activities


(1,278
)


(6,349
)CASH FLOWS FROM FINANCING ACTIVITIES:Proceeds from sale of common stock


717,000



50,000Proceeds from notes payable


-



60,000Payment on notes payable


(2,314
)


-Net cash provided by financing activities


714,686



110,000INCREASE (DECREASE) IN CASH


43,588



25,357BEGINNING BALANCE


69,433



1,051ENDING BALANCE

$
113,021


$
26,408Cash paid for income taxes

$
-


$
-Cash paid for interest

$
17,276


$
23,284Supplemental schedule of non-cash investing andfinancing activities:Issuance of common stock for Natural Resource Group, Inc. Common Stock

$
14,558


$
-Forgivness of related party notes

$
14,040


$
-Assumption of liabilites by former officer and shareholder

$
283,701


$
-




See accompanying notes to the financial statements.


6
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DIVERSIFIED RESOURCES INC.
 NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS
 April 30, 2014
   NOTE 1 – BASIS OF PRESENTATION


The interim consolidated financial statements of Diversified Resources, Inc. (“we”, “us”, “our”, “Diversified”, or the “Company”) are unaudited and contain all adjustments (consisting primarily of normal recurring accruals) necessary for a fair presentation of the results for the interim periods presented. Results for interim periods are not necessarily indicative of results to be expected for a full year or for previously reported periods due in part, but not limited to, interest rates, drilling risks, geological risks, the timing of acquisitions, and our ability to obtain additional capital. These interim financial statements should be read in conjunction with the audited financial statements and notes thereto included in Diversified’s Annual Report on Form 10-K for the year ended October 31, 2013 as filed with the Securities and Exchange Commission (“SEC”) on February 13, 2014 and the Form 8-K/A filed May 29, 2014 .  The accompanying consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America.
 
 The consolidated financial statements of the Company have been prepared pursuant to the rules and regulations of the SEC for Quarterly Reports on Form 10-Q and in accordance with US GAAP. Accordingly, these consolidated financial statements do not include all of the information and footnotes required by US GAAP for annual consolidated financial statements.
 
 Although, from a legal standpoint, we acquired Natural Resource Group, Inc. (“NRG”) on November 21, 2013, for financial reporting purposes the acquisition of NRG constituted a recapitalization, and the acquisition was accounted for as a reverse merger, whereby NRG was deemed to have acquired us.  Consequently, this report contains the historical financial statements of NRG for the three and six months ended April 30, 2014 and 2013.  From and after November 21, 2013, our financial statements have been consolidated with those of NRG, our wholly owned subsidiary.
 
 The consolidated financial statements are unaudited, but, in management's opinion, include all adjustments (which, unless otherwise noted, include only normal recurring adjustments) necessary for a fair presentation of such consolidated financial statements.
 
 NOTE 2 – ORGANIZATION AND GOING CONCERN
 
 Diversified Resources Inc. (“the Company”) was incorporated in the State of Nevada on March 19, 2009 to pursue mineral extraction in the United States.
 
 Effective November 21, 2013 we acquired 100% of the outstanding shares of Natural Resource Group, Inc. in exchange for 14,558,150 shares of our common stock
 
 NRG was incorporated in Colorado in 2000 but was relatively inactive until December 2010.  In December 2010, NRG acquired oil and gas wells, leases and other properties from Energy Oil and Gas, Inc.
 
 The accompanying financial statements have been prepared assuming that the Company will continue as a going concern; however, the conditions below raise substantial doubt about the Company’s ability to do so. 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 classifications of liabilities that may result should the Company be unable to continue as a going concern. The Company sustained operating losses during the years ended October 31, 2013 and 2012 and during the six months ended April 30, 2014 and 2013. The Company has a negative working capital in the amount of $611,487. The Company’s continuation as a going concern is dependent on its ability to generate sufficient cash flows from operations to meet its obligations and/or obtaining additional financing from its shareholders or other sources, as may be required.
   7
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   DIVERSIFIED RESOURCES INC.
 NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS
 April 30, 2014
   Management’s plans include obtaining additional debt or equity financing to fund operations; however, there can be no assurance that management will be successful in its efforts to obtain additional funding.
  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 area was the subject of a geological report on September 11, 2009.  The term of the lease is for 20 years and renewable for additional 20 years assuming all conditions of the lease are met. The lease was terminated on November 21, 2013 in connection with the acquisition of NRG.
  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 Diversified Resources, Inc.’s $0.001 par value common shares. The 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.
 
 NOTE 3 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
 
 Principles of Consolidation
 
 The accompanying consolidated unaudited financial statements include the accounts of Diversified Resources, Inc. and its wholly owned subsidiary, Natural Resource Group, Inc. Any inter-company accounts and transactions have been eliminated.
 
 Cash and cash equivalents
 
 The Company considers all liquid investments with a maturity of three months or less from the date of purchase that are readily convertible into cash to be cash equivalents.
 
 Use of estimates
 
 The preparation of 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 revenues and expenses during the reporting period.  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.
 
 Revenue Recognition
 
 We recognize oil and gas revenue from interests in producing wells as the oil and 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 April 30, 2014 and 2013 was immaterial.
 
 Accounting for Oil and Gas Activities
 
 Successful Efforts MethodWe 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.
   8
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   DIVERSIFIED RESOURCES INC.
 NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS
 April 30, 2014
   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 (“DD&A”) 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 ImpairmentWe 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 CostsGeological 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 $41,801 and $33,020 for the six months ended April 30, 2014 and 2013, respectively, and are included in Exploration Costs in the accompanying financial statements.
  Asset Retirement ObligationsAsset retirement obligations (ARO”) 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 and included in our DD&A 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.
   9
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  DIVERSIFIED RESOURCES INC.
 NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS
 April 30, 2014
   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 Company did not record any property impairment during the six months ended April 30, 2014 or 2013.
  Income Taxes
 
 We account for income taxes in accordance with Accounting Standards Codification (“ASC”) Topic 740, Income Taxes.  Under this standard, deferred tax liabilities and assets are determined based on the difference between the financial statement and tax bases of assets and liabilities using the enacted tax rates in effect for the year in which the differences are expected to reverse.  Deferred tax assets are reduced by a valuation allowance when we cannot make the determination that it is more likely than not that some portion or all of the related tax asset will be realized. Interest and penalties on tax deficiencies recognized in accordance with ACS accounting standards are classified as income taxes in accordance with ASC Topic 740-10-50-19.
  The Company follows ASC 740-10-05 Accounting for Uncertainty in Income Taxes. The Interpretation 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.
 
 Contingent Liabilities
 
 The Company records contingent liabilities when the amounts were incurred and determinable otherwise the Company will disclose the matter(s) and provide a range or best estimate of the contingency in the notes to the financial statements. There were no legal proceedings against the Company with respect to matters arising in the ordinary course of business. Neither the Company nor any of its officers or directors is involved in any other litigation either as plaintiffs or defendants, and have no knowledge of any threatened or pending litigation against them or any of the officers or directors. As of April 30, 2014, there were no contingent liabilities that required disclosure or accrual in the Company’s financial statements.
    10
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  DIVERSIFIED RESOURCES INC.
 NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS
 April 30, 2014
   Loss Per Share
 
 The Company computes net loss per share in accordance with ASC Topic 260, “Earnings per Share,” Under the provisions of the standard, basic and diluted 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. During periods when losses occur common stock equivalents, if any, are not considered in the computation as their effect would be anti-dilutive.
 
 Recent Accounting Pronouncements
 
 The Company does not believe that any recently issued accounting pronouncements will have a material impact on its financial position, results of operations or cash flows.
  NOTE 4 – Participation Agreement
  In connection with the convertible promissory note described in Note 6, the Company entered into a participation agreement with a nonaffiliated company whereby the maker of the promissory note 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. During 2012, $250,000 was advanced to the Company. In consideration of making the promissory note, 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 6).
  The modified net profits interest is based on the gross proceeds from the sale of oil, gas and other minerals in the four producing wells in the Garcia Field and three 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.
 
 NOTE 5 – Notes Payable
 
 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, Broomfield, Huerfano, Las Animas, Morgan and Weld Counties 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.  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 April 30, 2014 with interest accrued in the amount of $2,165.
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   DIVERSIFIED RESOURCES INC.
 NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS
 April 30, 2014
   NOTE 6 – Long-term Debt
  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, 2014.  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 terms provide for an initial draw of $150,000 with the potential for two subsequent draws of $100,000 each. The Company has drawn $250,000 on the facility and the balance at April 30, 2014 is $248,895. The lender has the right to convert the principal 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 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 $33,187 for the six months ended April 30, 2014 and 2013 respectively and $-0- and $17,475 for the three months ended April 30, 2014 and 2013 respectively. The Company reviewed the conversion feature for beneficial conversion features and embedded derivatives, and determined that neither applied.
  Convertible Promissory Note—On May 18, 2012 the Company entered into a $70,000 convertible promissory note bearing interest at 10%, due May 31, 2014. The note is collateralized by a second priority deed of trust on all the wells, equipment and approximately 4,600 acres of oil and gas leasehold interests in the Garcia Field. The lender has the right to convert the principal balance to a 2% working interest in the collateral or 70,000 shares of the Company’s $0.0001 par value common stock. In the event the principal is less than $70,000, the conversion 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 reviewed the conversion feature for beneficial conversion features and embedded derivatives, and determined that neither applied.
  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:
 2014


2013Convertible promissory note


248,895



248,895Debt Discount, net of amortization


--



(19,516
)Convertible promissory note


70,000



70,000Installment loan


16,143



18,457335,038



317,836Current portion long term debt


(4,692
)


(4,692
)Current portion promissory notes


(318,895
)


(299,379
)Long term debt


11,451



13,765
 
 NOTE 7 – INCOME TAXES
 
 No provision was made for federal income tax for the three and six months ended April 30, 2014 and 2013, since the Company had net operating losses.
 
 NOTE 8 – STOCKHOLDERS’ EQUITY
 
 The Company is authorized to issue 450,000,000 common shares of par value at $0.001 and 50,000,000 preferred shares of par value at $0.001. As of April 30, 2014, 18,445,867 shares of common stock and no preferred shares were issued and outstanding.
   12
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   DIVERSIFIED RESOURCES INC.
 NOTES TO THE UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS
 April 30, 2014
   During the six months ended April 30, 2014, the Company issued 1,317,750 shares of its $0.001 par value common stock in consideration of $717,000.
 
 NOTE 9 – RELATED PARTY TRANSACTIONS
 
 During the year ended October 31, 2013, Philip F. Grey, the President loaned $14,040, to the Company.  The loan was payable on demand, carried no interest and had no maturity date.  Philip F. Grey forgave the $14,040 loan as of November 21, 2013.
  Natural Resource Group, Inc. has an office 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 the office space for a 3 year period ending July 1, 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 $10,667 and accrued $5,333 in the six months ended April 30, 2014.  The Company has accrued liability in the amount of $13,333 for accrued rent.  Natural Resource Group, Inc. 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 Company paid a director and shareholder $78,950 and $0 in the six months ended April 30, 2014 and 2013 respectively for financial public relations consulting.
  The Company paid the President’s brother $24,000 and $600 in the six months ended April 30, 2014, and 2013 respectively for landman consulting services.  No fees for landman consulting services were paid in the three months ended April 30, 2014 and 2013 respectively.
  NOTE 10 – COMMITMENTS AND CONTINGENCIES
  Legal--We are 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.
  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.
  NOTE 11 – SUBSEQUENT EVENTS
  The Company issued 1,260,000 shares of the Company’s $0.001 par value common stock for $630,000 in cash in May and June 2014.




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ITEM 2.  MANAGEMENT'S DISCUSSIONAND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS





The following discussion should be read in conjunction with our financial statements included as part of this report.





We were incorporated on March 19, 2009 in Nevada.  In 2009, we leased two unpatented mining claims located in Esmeralda County, Nevada.  In January 2011, we staked an additional twenty unpatented mining claims in the same area.  Due to the lack of capital, we  terminated the mining lease in November 2013. We have no plans to conduct any work on the unpatented mining claims.





On November 21, 2013 we acquired 100% of the outstanding shares of Natural Resource Group, Inc. in exchange for 14,558,150 shares of our common stock.





Unless otherwise indicated, all references to us include the operations of NRG.





NRG was incorporated in Colorado in 2000 but was relatively inactive until December 2010.  In December 2010, NRG acquired oil and gas wells, leases and other properties from Energy Oil and Gas, Inc.





In December 2010 NRG acquired oil and gas properties from Energy Oil and Gas, Inc. for 2,500,000 shares of its common stock and a promissory note in the principal amount of $360,000.  As of April 30, 2014, the principal amount of this note was $107,070.





Included as part of the acquisition were:





Garcia Field





●
leases covering 4,600 gross (4,600 net) acres,●
four wells which produce natural gas and naturals gas liquids;●
a refrigeration/compression plant which separates natural gas liquids from gas produced from the four wells; and●
one injection well;





Denver-Julesburg Basin





●
leases covering 1,400 gross (1,400 net) acres,●
three shut-in wells which need to be recompleted; and●
three producing oil and gas wells.





Subsequent to December 2010, leases covering 160 acres in the Garcia Field were sold and leases covering 960 acres in the Garcia Field expired.  In 2013, we acquired a 640 acre lease (100% working interest, 80% net revenue interest) in the D-J Basin.





The Garcia Field is located in Las Animas County, Colorado, approximately 10 miles from Trinidad, Colorado.





The Denver/Julesburg (“D-J”) Basin is located in Northeastern Colorado:






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The following table shows our net production of oil, gas and natural gas liquids for the periods indicated:


Six Months Ended April 30,2014


2013Production:Oil (Bbls)


0



0Gas (Mcf)


1,341



1,057Natural Gas Liquids (gallons)


15,122



4,141
 
 The following table shows, as of April 30 2014, our producing wells, developed acreage, and undeveloped acreage, excluding service (injection and disposal) wells:





Productive Wells


Developed Acreage


Undeveloped Acreage(1)Location

Gross


Net


Gross


Net


Gross


NetColorado:Garcia Field


5



5



200



200



4,400



4,400D-J Basin


4



3.75



160



160



760



760





(1)
Undeveloped acreage includes leasehold interests on which wells have not been drilled or completed to the point that would permit the production of commercial quantities of natural gas and oil regardless of whether the leasehold interest is classified as containing proved undeveloped reserves.





As of April 30, 2014 we were not drilling, or reworking any oil or gas wells and one well in the Garcia Field was awaiting completion.





During the twelve months ending April 30, 2015, we plan to:





●
recomplete the three shut-in wells we acquired from Energy Oil and Gas, at a cost of approximately $130,000 per well;●
drill up to eight additional wells to the Sussex formation (5,700 feet) in the D-J Basin.  The cost to drill, and if warranted complete, each well will be approximately $350,000; and●
drill at least one well in the D-J Basin to the Codell/Niobrara formations (7,800 feet).  The cost to drill, and if warranted complete, the well will be approximately $800,000.





Results of Operations





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. The then President of the Company sold 2,680,033 shares of the Company’s common stock to the Company for nominal consideration.  The 2,680,033 shares 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 and was accounted for as a recapitalization of the Company whereby NRG was the accounting acquirer and issued 5,250,000 shares of common stock for the net assets of the Company.





The financial statements of NRG as of October 31, 2013 and, 2012 were included as part of an 8-K/A report we filed with the Securities and Exchange Commission on May 29, 2014.  The 8-K/A can be reviewed on the SEC’s website (www.sec.gov).





Material changes of certain items in our statements of operations included in our financial statements for the periods presented are discussed below.






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For the three months ended April 30, 2014 compared to the three months ended April 30, 2013





For the three months ended  April 30, 2014 we reported a loss of $(380,015) or $(0.02) per share compared with a net loss of $(140,414) or $(0.01) per share for the three months ended April 30, 2013. The increase in the net loss of $(239,601) principally arises from increased operations and costs associated with becoming a public company in the period ending April 30, 2014 versus being a private company in the same period in 2013.





Oil and gas sales were $9,874 and $11,481 for the three months ending April 30, 2014 and 2013 respectively; a decrease of $1,607 (14%).  The decrease is principally attributable to certain of our DJ Basin wells being shut-in for repairs partially offset by increased price of the natural gas and natural gas liquids sold.




Exploration costs were $19,984 and $16,500 for the three months ending April 30, 2014 and 2013 respectively; an increase of $3,484 (21%).   The increase is principally attributable to increased geological consulting and is considered normal in the ordinary course of business.




Lease operating expenses were $66,372 and $30,086 for the three months ending April 30, 2014 and 2013 respectively; an increase of $36,286 (121%).  The increase is principally attributable to additional compressor leases at the Garcia Field.Increased compression expenses arose because the Company added additional compression facilities at the Garcia Field not present in 2013. The fluctuations are considered normal in the ordinary course of business.




General and administrative expenses were $309,124 and $65,253 for the three months ending April 30, 2014 and 2013 respectively; an increase of $243,871 (374%).  Professional services and other consultants accounted for approximately $235,009 of the increase and the balance of $8,862 consisted of miscellaneous general and administrative expenses.  The increase in professional and consulting services is attributable to with becoming a public company in period ending April 30, 2014 versus being a private company in the same period in 2013.  The increase in other miscellaneous expenses is considered normal in the ordinary course of business.




Depreciation expense was $3,679 and $1,035 for the three months ending April 30, 2014 and 2013 respectively; an increase of $2,644 (255%). The increase arises from the Company adding additional equipment in the 2014 period.




Depletion expense was $1,800 and $3,000 for the three months ending April 30, 2014 and 2013 respectively; a decrease of $1,200 (40%). The decrease arises from the decreased production in 2014 period.




Accretion expense was $2,000 and $5,200 for the three months ending April 30, 2014 and 2013 respectively; a decrease of $3,200 (62%).  The decrease is a result of changes in the estimated asset retirement obligation assumptions.




Interest expense was $13,070 and $30,821 for the three months ending April 30, 2014 and 2013 respectively; a decrease of $17,751 (58%). The decrease arises from decreased amortization of the debt discount which concluded in January 2014.





For the six months ended April 30, 2014 compared to the six months ended April 30, 2013





For the six months ended  April 30, 2014 we reported a loss of $(715,860) or $(0.04) per share compared with a net loss of $(266,852) or $(0.02) per share for the six months ended April 30, 2013. The increase in the net loss of $(449,008) principally arises from increased operations and costs associated with becoming a public company in the period ending April 30, 2014 versus being a private company in the same period in 2013.




Oil and gas sales were $22,640 and $32,113 for the six months ending April 30, 2014 and 2013 respectively; a decrease of $9,473 (29%).  The decrease is principally attributable to certain of our DJ Basin wells being shut-in for repairs.




Exploration costs were $41,801 and $33,020 for the six months ending April 30, 2014 and 2013 respectively; an increase of $8,781 (27%).   The increase is principally attributable to increased geological consulting and is considered normal in the ordinary course of business.






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Lease operating expenses were $122,018 and $36,530 for the six months ending April 30, 2014 and 2013 respectively; an increase of $85,488 (234%). The increase is principally attributable to additional compressor leases at the Garcia Field.Increased compression expenses arose because the Company added additional compression facilities at the Garcia Field not present in 2013. The fluctuations are considered normal in the ordinary course of business.
 
 General and administrative expenses were $515,622 and $115,100 for the six months ending April 30, 2014 and 2013 respectively; an increase of $400,522 (348%).  The following table summarizes the fluctuations.





Professional Fees

$
183,397Land and engineering consultants


48,664Travel


10,742Financial public relations consultants


102,788Insurance


9,695Filing fees and stock transfer costs


16,348Taxes


5,950Miscellaneous other


22,938$
400,522





Professional fees, land and engineering consultants, financial public relation consultants and filing fees and stock transfer costs increases are a result of the Company becoming public in the six months ending April 30, 2014 as opposed to being private in the six months ending April 30, 2013 and are considered normal in the ordinary course of business.




Increases in insurance, filing fees, taxes and miscellaneous costs are considered normal in the ordinary course of business.




Depreciation expense was $7,358 and $1,968 for the six months ending April 30, 2014 and 2013 respectively; an increase of $5,390 (274%). The increase arises from the Company adding additional equipment in the 2014 period.




Depletion expense was $4,100 and $7,400 for the six months ending April 30, 2014 and 2013 respectively; a decrease of $3,300 (45%). The decrease arises from the decreased production in 2014 period.




Accretion expense was $4,000 and $10,400 for the six months ending April 30, 2014 and 2013 respectively; a decrease of $6,400 (62%).  The decrease is a result of changes in the estimated asset retirement obligation assumptions.




The Company incurred a loss on the disposal of oil and gas compression equipment in the six months ended April 30, 2013 of $54,480, and $0 in the six months ending April 30, 2014 because the Company did not have any disposals in the 2014 period.




Interest expense was $43,601 and $60,067 for the six months ending April 30, 2014 and 2013 respectively; a decrease of $16,466 (27%). The decrease arises from decreased amortization of the debt discount which concluded in January 2014.








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Liquidity and Capital Resources





Our sources and (uses) of funds for the six months ended April 30, 2014 and 2013 are shown below:




Six Months ended April 30,2014


2013Cash used in operations

$
(669,820
)

$
(78,294
)Purchase of oil and gas properties


--



4,140Purchase of equipment


(1,278
)


(2,209
)Sale of common stock


717,000



50,000Loans


--



60,000Payment on notes payable


(2,314
)


--





Between December 2013 and April 30, 2014 we sold 1,317,750shares of our common stock to a group of private investors for cash of $717,000.




As of April 30, 2014, operating expenses were approximately $85,900 per month, which amount includes salaries and other corporate overhead, but excludes expenses associated with drilling, completing or reworking wells, lease operating expenses and interest expense.




The Company’s material future contractual obligations as of April 30, 2014 are summarized as follows:





Total


10/31/14


10/31/2015


10/31/2016


Thereafter$
442,108


$
321,242


$
111,762


$
4,692


$
4,412





We estimate our capital requirements for the twelve months ending April 30, 2015 will be as follows:





●
Drilling, completing, and fracturing wells

$
1,740,000●
Install gathering line (1)

$
150,000●
Seismic work

$
120,000





(1)
If installed, the line will transport gas from the new wells we plan to drill and complete in the Garcia field to our refrigeration/compression plant.





Any cash generated by operations, after payment of general, administrative and lease operating expenses, will be used to drill and, if warranted, complete oil/gas/ngl wells, acquire oil and gas leases covering lands which are believed to be favorable for the production of oil, gas, and natural gas liquids, and to fund working capital reserves.  Our capital expenditure plans are subject to periodic revision based upon the availability of funds and expected return on investment.






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Trends




The factors that will most significantly affect future operating results will be:





●
the sale prices of crude oil;●
the amount of production from oil, gas and gas liquids wells in which we have an interest;●
lease operating expenses;●
the availability of drilling rigs, drill pipe and other supplies and equipment required to drill and complete oil wells; and●
corporate overhead costs.





Revenues will also be significantly affected by our ability to maintain and increase oil, gas and natural gas liquids production.





Other than the foregoing, we do not know of any trends, events or uncertainties that have had, or are reasonably expected to have, a material impact on our revenues or expenses.





It is expected that our principal source of cash flow will be from the sale of crude oil, natural gas and natural gas liquids which are depleting assets. Cash flow from the sale of oil/gas/ngl production depends upon the quantity of production and the price obtained for the production. An increase in prices will permit us to finance operations to a greater extent with internally generated funds, may allow us to obtain equity financing more easily or on better terms. However, price increases heighten the competition for oil prospects, increase the costs of exploration and development, and, because of potential price declines, increase the risks associated with the purchase of producing properties during times that prices are at higher levels.





A decline in hydrocarbon prices (i) will reduce cash flow which in turn will reduce the funds available for exploring for and replacing reserves, (ii) will increase the difficulty of obtaining equity and debt financing and worsen the terms on which such financing may be obtained, (iii) will reduce the number of  prospects which have reasonable economic terms, (iv) may cause us to permit leases to expire based upon the value of potential  reserves in relation to the costs of exploration, (v) may result in marginally productive wells being abandoned as non-commercial, and (vi) may increase the difficulty of obtaining financing. However, price declines reduce the competition for oil properties and correspondingly reduce the prices paid for leases and prospects.





We plan to generate profits by acquiring, drilling and/or completing productive wells.  However, we plan to obtain the funds required to drill, and if warranted, complete new wells with any net cash generated by operations, through the sale of securities, from loans from third parties or from third parties willing to pay our share of the cost of drilling and completing the wells as partners/participants in the resulting wells.  We do not have any commitments or arrangements from any person to provide it with any additional capital.  We may not be successful in raising the capital needed to drill oil wells.  Any wells which may be drilled may not produce oil.





Other than as disclosed above, we do not know of any:





●
trends, demands, commitments, events or uncertainties that will result in, or that are reasonably likely to result in, any material increase or decrease in liquidity; or●
significant changes in expected sources and uses of cash.





Critical Accounting Policies and Estimates





See Notes 2 and 3 to the financial statements included as part of this report for a description of our critical accounting policies.





Recent Accounting Pronouncements





We do not believe that any recently issued accounting pronouncements will have a material impact on our financial position, results of operations or cash flows.






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ITEM 3.  QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT MARKET RISKS





Not applicable.





ITEM 4.  CONTROLS AND PROCEDURES.





Evaluation of Disclosure Controls and Procedures





An evaluation was carried out under the supervision and with the participation of our management, including our Principal Executive Officer and Principal Financial Officer, of the effectiveness of our disclosure controls and procedures as of the end of the period covered by this report on Form 10-Q.  Disclosure controls and procedures are procedures designed with the objective of ensuring that information required to be disclosed in our reports filed under the Securities Exchange Act of 1934, such as this Form 10-Q, is recorded, processed, summarized and reported, within the time period specified in the Securities and Exchange Commission’s rules and forms, and that such information is accumulated and is communicated to our management, including our Principal Executive Officer and Principal Financial Officer, or persons performing similar functions, as appropriate, to allow timely decisions regarding required disclosure.  Based on that evaluation, our management concluded that, as of April 30, 2014, our disclosure controls and procedures were effective.





Changes in Internal Control Over Financial Reporting





There were no changes in our internal control over financial reporting during the quarter ended April 30, 2014, that materially affected or are reasonably likely to materially affect our internal control over financial reporting.





PART II








ITEM 2.  UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS.




During the quarter ended April 30, 2014 the Company sold 1,124,000 shares of its common stock to private investors at a price of $0.50 per share. The $562,000 in proceeds was used for operations. The Company relied upon the exemption provided by Section 4(2) of the Securities Act of 1933 in connection with the sale of these shares. The persons who acquired these shares were sophisticated investors and was provided full information regarding the Company's business and operations. There was no general solicitation in connection with the offer or sale of these securities. The persons who acquired these shares acquired them for their own accounts. The certificates representing these shares will bear a restricted legend providing that they cannot be sold except pursuant to an effective registration statement or an exemption from registration. No commission was paid to any person in connection with the sale of these shares.





ITEM 6.  EXHIBITS





31.1
Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 for Paul Laird.31.2
Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 for Paul Laird.32
Certification pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 for Paul Laird.














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SIGNATURES





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






DIVERSIFIED RESOURCES, INC.Date: June 16, 2014
By:
/s/ Paul LairdPaul Laird, Principal Executive, Financial andAccounting Officer