jani_10q.htm

0001477932-13-002455.txt : 20130515 0001477932-13-002455.hdr.sgml : 20130515 20130515132845 ACCESSION NUMBER: 0001477932-13-002455 CONFORMED SUBMISSION TYPE: 10-Q PUBLIC DOCUMENT COUNT: 12 CONFORMED PERIOD OF REPORT: 20130331 FILED AS OF DATE: 20130515 DATE AS OF CHANGE: 20130515 FILER: COMPANY DATA: COMPANY CONFORMED NAME: Janus Resources, Inc. CENTRAL INDEX KEY: 0001016708 STANDARD INDUSTRIAL CLASSIFICATION: OIL AND GAS FIELD EXPLORATION SERVICES [1382] IRS NUMBER: 980170247 STATE OF INCORPORATION: NV FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-Q SEC ACT: 1934 Act SEC FILE NUMBER: 000-30156 FILM NUMBER: 13845436 BUSINESS ADDRESS: STREET 1: 430 PARK AVE. STREET 2: SUITE 702 CITY: NEW YORK STATE: NY ZIP: 10022 BUSINESS PHONE: 212-246-3030 MAIL ADDRESS: STREET 1: 430 PARK AVE. STREET 2: SUITE 702 CITY: NEW YORK STATE: NY ZIP: 10022 FORMER COMPANY: FORMER CONFORMED NAME: ENTHEOS TECHNOLOGIES INC DATE OF NAME CHANGE: 20001002 FORMER COMPANY: FORMER CONFORMED NAME: WHATSONLINE COM INC DATE OF NAME CHANGE: 19990722 FORMER COMPANY: FORMER CONFORMED NAME: FAR WEST RESOURCES INC DATE OF NAME CHANGE: 19980112 10-Q 1 jani_10q.htm FORM 10-Q jani_10q.htm

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

x QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2013

¨ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from _____ to _____

Commission File Number: 000-30156

JANUS RESOURCES, INC.

(Exact name of registrant as specified in its charter)

Nevada		98-0170247
(State or other jurisdiction of incorporation)		(I.R.S. Employer Identification No.)

430 Park Avenue, Suite 702, New York, NY		10022
(Address of principal executive offices)		(Zip Code)

800-755-5815

(Registrant’s telephone number, including area code)

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

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

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

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

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

As of May 15, 2013, the registrant had 63,075,122 shares of its common stock, par value $0.00001 per share, issued and outstanding.

TABLE OF CONTENTS

PART I - FINANCIAL INFORMATION

Item 1.	Financial Statements
	Consolidated Balance Sheets	3
	Consolidated Statements of Operations	4
	Consolidated Statements of Comprehensive Loss	5
	Consolidated Statements of Stockholders’ Equity (Deficit)	6
	Consolidated Statements of Cash Flows	7
	Notes to Consolidated Financial Statements	8

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	15

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	20

Item 4.	Controls and Procedures	21

PART II - OTHER INFORMATION

Item 1.	Legal Proceedings	22

Item 1A.	Risk Factors	22

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	22

Item 6.	Exhibits	22

	Signatures	23

PART I — FINANCIAL INFORMATION

Item 1. Financial Statements

JANUS RESOURCES, INC.

CONSOLIDATED BALANCE SHEETS

	March 31,			December 31,
	2013			2012
	(unaudited)
ASSETS
Current assets
Cash and cash equivalents	$	490,050		$	513,595
Accounts receivable		-			800
Prepaid expenses		-			7,562
Total current assets		490,050			521,957

Oil and gas properties
Unproven properties		-			537,501
Accumulated depreciation, depletion, amortization and impairment		-			(513,374	)
Oil and gas properties, net		-			24,127
Mineral properties		519,750			519,750

Total assets	$	1,009,800		$	1,065,834

LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities
Accounts payable and accrued liabilities	$	22,415		$	30,905
Accounts payable - related parties		40,661			9,638
Total current liabilities		63,076			40,543

Asset retirement obligation		-			57,532
Total liabilities		63,076			98,075

STOCKHOLDERS' EQUITY
Preferred stock: $0.0001 par value: Authorized: 10,000,000 shares,
Issued and outstanding: nil		-			-
Common stock: $0.00001 par value: Authorized: 200,000,000 shares,
Issued and outstanding: 63,075,122 shares (2012: 63,075,122)		631			631
Additional paid-in capital		5,462,236			5,462,236
Accumulated deficit		(4,512,039	)		(4,491,004	)
Accumulated other comprehensive loss		(4,104	)		(4,104	)
Total stockholders' equity		946,724			967,759
Total liabilities and stockholders' equity	$	1,009,800		$	1,065,834

(The accompanying notes are an integral part of these consolidated financial statements)

JANUS RESOURCES, INC.

CONSOLIDATED STATEMENT OF OPERATIONS

(unaudited)

	For the Three Months Ended March 31,
	2013			2012

Revenue
Oil and gas sales	$	-		$	6,053

Expenses
Lease operating expenses		-			5,025
Exploration costs		-			3,138
General and administrative expenses		70,372			80,812
Impairment and depreciation		-			331
Total operating expenses		70,372			89,306

Operating Loss		(70,372	)		(83,253	)

Other income
Gain on disposal of oil and gas properties		49,337			-
Total other income		49,337			-

Net loss	$	(21,035	)	$	(83,253	)

Earnings per share - basic and diluted
Loss per common share	$	(0.00	)	$	(0.00	)

Weighted average shares outstanding		63,075,122			63,075,122

(The accompanying notes are an integral part of these consolidated financial statements)

JANUS RESOURCES, INC.

CONSOLIDATED STATEMENT COMPREHENSIVE LOSS

(unaudited)

	For the Three Months Ended March 31,
	2013			2012

Net loss	$	(21,035	)	$	(83,253	)
Other comprehensive loss
Foreign currency translation adjustments		-			(769	)
Total comprehensive loss	$	(21,035	)	$	(84,022	)

(The accompanying notes are an integral part of these consolidated financial statements)

JANUS RESOURCES, INC.

CONSOLIDATED STATEMENT STOCKHOLDER’S EQUITY

(unaudited)

										Accumulated
										other			Total
	Common Stock				Additional		Accumulated			comprehensive			stockholders'
	Shares		Amount		paid-in capital		(deficit)			(loss)			equity

Balance, December 31, 2011		63,075,122	$	631	$	5,462,236	$	(4,247,045	)	$	(4,104	)	$	1,211,718

Net loss, December 31, 2012		-		-		-		(243,959	)		-			(243,959	)

Balance, December 31, 2012		63,075,122		631		5,462,236		(4,491,004	)		(4,104	)		967,759

Net loss, March 31, 2013		-		-		-		(21,035	)		-			(21,035	)

Balance, March 31, 2013		63,075,122	$	631	$	5,462,236	$	(4,512,039	)	$	(4,104	)	$	946,724

(The accompanying notes are an integral part of these consolidated financial statements)

JANUS RESOURCES, INC.

CONSOLIDATED STATEMENT OF CASH FLOWS

(unaudited)

	For the Three Months Ended March 31,
	2013			2012

Cash flows from operating activities:
Net loss	$	(21,035	)	$	(83,253	)
Adjustments to reconcile net loss to
net cash flows from operating activities:
Impairment and depreciation		-			331
Accretion of asset retirement obligation		-			729
Gain on disposal of oil and gas properties		(49,337	)		-
Changes in operating assets and liabilities:
Decrease (increase) in receivables		800			6,752
Decrease (increase) in prepaid expenses		7,562			(10,200	)
(Decrease) increase in accounts payable
and accrued liabilities including related party payables		35,465			(40,056	)
Net cash flows from operating activities		(26,545	)		(125,697	)

Cash flows from investing activities:
Proceeds from disposal of oil and gas properties		3,000			-
Net cash flows from investing activities		3,000			-

Effect of exchange rate changes on cash and cash equivalents		-			(769	)
Decrease in cash and cash equivalents		(23,545	)		(126,466	)
Cash and cash equivalents, beginning of period		513,595			787,771
Cash and cash equivalents, end of period	$	490,050		$	661,305


Supplemental disclosure of cash flow information:
Interest paid in cash	$	-		$	-
Income tax paid in cash	$	-		$	-

(The accompanying notes are an integral part of these consolidated financial statements)

JANUS RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

1. Organization, Nature and Continuance of Operations

Janus Resources, Inc. (formerly Entheos Technologies, Inc.) (the “Company”, “we”, “us”, and “our”) is in the business of locating, acquiring, exploring and, if warranted, developing both mineral exploration properties and oil and gas properties. The Company pursues oil and gas prospects in partnership with oil and gas companies with exploration, development and production expertise. Prior to February 2013 the Company had non-operating, minority working interests in oil and gas properties. The properties were sold on February 18 and 19, 2013. On June 8, 2011, the Company completed the acquisition of the Fostung tungsten property, located in Foster Township, Sudbury, Ontario, Canada.

The Company’s general business strategy is to acquire mineral properties and oil and gas properties either directly or through the acquisition of operating entities. Its continued operations and the recoverability of property costs are dependent upon the existence of economically recoverable mineral and oil and gas reserves, the confirmation of its interest in the underlying properties, its ability to obtain necessary financing to complete development, and future profitable production.

The Company has recently incurred net operating losses and operating cash flow deficits. The Company’s accumulated deficit is $4,512,039 as of March 31, 2013. It may continue to incur losses from operations and operating cash flow deficits in the future. Management believes that the Company’s cash and cash equivalent balances, anticipated cash flows from operations and other external sources of credit will be sufficient to meet its cash requirements for the next twelve months if not further. The future of the Company after March 2014 will depend in large part on its ability to successfully generate cash flows from operations and raise capital from external sources to fund operations.

2. Significant Accounting Policies

Basis of Presentation and Principles of Accounting

The interim consolidated financial statements included herein have been prepared by the Company, without audit, in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”) pursuant to Part 210 of Regulation S-X. Certain information and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“US GAAP”) have been condensed or omitted pursuant to such SEC rules and regulations, although the Company believes that the disclosures included are adequate to make the information presented not misleading.

In management’s opinion, the unaudited consolidated financial statements contained herein reflect all adjustments, consisting solely of normal recurring items, which are necessary for the fair presentation of our financial position, results of operations, and cash flows on a basis consistent with that of our prior audited consolidated financial statements. The Company has evaluated information about subsequent events that became available to them through the date the financial statements were issued. This information relates to events, transactions or changes in circumstances that would require us to adjust the amounts reported in the financial statements or to disclose information about those events, transactions or changes in circumstances. However, the results of operations for interim periods may not be indicative of results to be expected for the full fiscal year. Therefore, these financial statements should be read in conjunction with the Company’s audited consolidated financial statements including the notes thereto for the year ended December 31, 2012, which may be found under the Company’s profile on EDGAR.

The accounting policies followed by the Company are set out in Note 2 to the audited consolidated financial statements for the year ended December 31, 2012 and have been consistently followed in the preparation of these consolidated interim financial statements.

Principles of Consolidation

These interim consolidated financial statements have been prepared in accordance with US GAAP and include the accounts of the Company and its wholly-owned subsidiaries, Fostung Resources, Limited (“Fostung”) and Entheos Energy, Inc. (“Entheos”). Collectively, they are referred to herein as “the Company.” All significant intercompany transactions and balances have been eliminated. Fostung was formed on incorporated on May 10, 2011, in Ontario Canada. Entheos was incorporated under the laws of the State of Nevada on October 5, 2000.

Applicable Accounting Guidance

Any reference in these notes to applicable accounting guidance is meant to refer to the authoritative non-governmental United States GAAP as found in the Financial Accounting Standards Board’s (“FASB”) Accounting Standards Codification (“ASC”).

Accounting Estimates

The preparation of consolidated 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 reported amounts of assets and liabilities and the reported amounts of revenues and expenses during the reporting period. Significant areas requiring the use of management estimates include the determination of impairment of mineral properties, valuation allowances for future income tax assets, fair value of non-cash stock-based compensation, common stock warrants and reclamation and environmental obligations. Actual results, as determined by future events, may differ from these estimates. Management’s judgments and estimates in these areas are based on information available from both internal and external sources, including engineers, geologists, consultants and historical experience in similar matters.

Cash and Cash Equivalents

The Company considers all highly liquid instruments purchased with an original maturity of three months or less to be cash equivalents. The Company did not have any cash equivalents at March 31, 2013 and December 31, 2012.

Mineral Properties

The Company has concluded that mineral rights meet the definition of tangible assets. Accordingly, the Company accounts for its mineral properties on a cost basis whereby all direct costs, net of pre-production revenue, relative to the acquisition of the properties are capitalized. All sales and option proceeds received are first credited against the costs of the related property, with any excess credited to earnings. Once commercial production has commenced, the net costs of the applicable property will be charged to operations using the unit-of-production method based on estimated proven and probable recoverable reserves. The net costs related to abandoned properties are charged to operations.

Costs of exploring, carrying and retaining unproven properties are charged to operations as incurred until such time that proven reserves are discovered. From that time forward, the Company will capitalize all costs to the extent that future cash flow from mineral reserves equals or exceeds the costs deferred. The deferred costs will be amortized over the recoverable reserves when a property reaches commercial production. As at March 31, 2013 and December 31, 2012, the Company did not have proven reserves. Exploration activities conducted jointly with others are reflected at the Company's proportionate interest in such activities.

Full Cost Method of Accounting for Oil and Gas Properties

The Company has elected to utilize the full cost method of accounting for its oil and gas activities. In accordance with the full cost method of accounting, all costs associated with acquisition, exploration, and development of oil and gas reserves, including directly related overhead costs and related asset retirement costs are capitalized.

All capitalized costs of oil and gas properties, including the estimated future costs to develop proved reserves, are amortized on the unit-of-production method using estimates of proved reserves once proved reserves are determined to exist. The Company did not establish proved reserves for oil and gas properties during the periods presented and as such did not record amortization.

Oil and gas properties without estimated proved reserves are assessed for impairment at each reporting date. As a result of management’s impairment analysis, the Company recorded an impairment loss of $nil and $331 during the three month periods ended March 31, 2013 and 2012, respectively.

Sales of oil and gas properties are accounted for as adjustments of capitalized costs with no gain or loss recognized, unless such adjustments would significantly alter the relationship between capitalized costs and proved reserves of oil and gas, in which case the gain or loss is recognized in income. On February 18, 2013 and February 19, 2013 the Company sold its interests in all of its oil and gas properties. During the three month period ended March 31, 2013, a gain of $49,337 was recognized in income as there are no longer any oil and gas capitalized costs.

Asset Retirement Obligation

The Company records the fair value of the liability for closure and removal costs associated with the legal obligations upon retirement or removal of any tangible long-lived assets by recording the fair value of the liability during the period in which it was incurred. The associated asset retirement costs are capitalized as part of the carrying amount of the long-lived asset. The increase in carrying value of a property associated with the capitalization of an asset retirement obligation is included in oil and gas properties in the balance sheets. The Company’s asset retirement obligation consists of costs related to the plugging of wells, removal of facilities and equipment and site restoration on its oil and gas properties. The asset retirement liability is allocated to operating expense using a systematic and rational method. Asset retirement obligations amounted to $nil and $57,532 at March 31, 2013 and December 31, 2012, respectively. See “Note 3. Oil and Gas Properties” for further discussion.

Impairment of Long-Lived Assets

The Company reviews and evaluates its long-lived assets for impairment at each balance sheet date and documents such impairment testing. The tests include an evaluation of the assets and events or changes in circumstances that would indicate that the related carrying amounts may not be recoverable.

Oil and gas properties are subject to a “ceiling test” which basically limits capitalized costs to the sum of the estimated future net revenues from proved reserves, discounted at 10% per annum to present value, based on current economic and operating conditions, adjusted for related income tax effects.

Mineral properties in the exploration stage are monitored for impairment based on factors such as the Company’s continued right to explore the area, exploration reports, assays, technical reports, drill results and the Company’s continued plans to fund exploration programs on the property, whether sufficient work has been performed to indicate that the carrying amount of the mineral property cost carried forward as an asset will not be fully recovered, even though a viable mine has been discovered.

The tests for long-lived assets in the exploration, development or producing stage that would have a value beyond proven and probable reserves would be monitored for impairment based on factors such as current market value of the mineral property and results of exploration, future asset utilization, business climate, mineral prices and future undiscounted cash flows expected to result from the use of the related assets. Recoverability of assets to be held and used is measured by a comparison of the carrying amount of an asset to the estimated future net undiscounted cash flows expected to be generated by the asset, including evaluating its reserves beyond proven and probable amounts.

The Company’s policy is to record an impairment loss in the period when it is determined that the carrying amount of the asset may not be recoverable either due to impairment or by abandonment of the property. The impairment loss is calculated as the amount by which the carrying amount of the asset exceeds its fair value. While the Company incurred losses from operations, these losses have not been in excess of planned expenditures on the specific mineral properties in order to ultimately realize their value.

Oil and Gas Revenue Recognition

The Company recognizes oil and gas revenues when oil and gas production is sold to a purchaser at a fixed or determinable price, when delivery has occurred and title has transferred, and if collectability of the revenue is probable. Delivery occurs and title is transferred when production has been delivered to a purchaser’s pipeline or truck. As a result of the numerous requirements necessary to gather information from purchasers or various measurement locations, calculate volumes produced, perform field and wellhead allocations, distribute and disburse funds to various working interest partners and royalty owners, the collection of revenues from oil and gas production may take up to 45 days following the month of production. Therefore, the Company may make accruals for revenues and accounts receivable based on estimates of its share of production. Since the settlement process may take 30 to 60 days following the month of actual production, its financial results may include estimates of production and revenues for the related time period. The Company will record any differences between the actual amounts ultimately received and the original estimates in the period they become finalized.

Income Taxes

The Company recognizes income taxes on an accrual basis based on tax position taken or expected to be taken in our tax returns. A tax position is defined as a position in a previously filed tax return or a position expected to be taken in a future tax filing that is reflected in measuring current or deferred income tax assets and liabilities. Tax positions are recognized only when it is more likely than not (i.e., likelihood of greater than 50%), based on technical merits, that the position would be sustained upon examination by taxing authorities. Tax positions that meet the more likely than not threshold are measured using a probability-weighted approach as the largest amount of tax benefit that is greater than 50% likely of being realized upon settlement. Income taxes are accounted for using an asset and liability approach that requires the recognition of deferred tax assets and liabilities for the expected future tax consequences of events that have been recognized in our financial statements or tax returns. A valuation allowance is established to reduce deferred tax assets if all, or some portion, of such assets will more than likely not be realized. Should they occur, our policy is to classify interest and penalties related to tax positions as interest expense. Since our inception, no such interest or penalties have been incurred.

Earnings (Loss) Per Share

The Company presents both basic and diluted earnings per share (“EPS”) amounts. Basic EPS is calculated by dividing net income by the weighted average number of common shares outstanding during the period presented. Diluted EPS amounts are based upon the weighted average number of common and common equivalent shares outstanding during the period presented. There were no dilutive shares outstanding for the three month period ended March 31, 2013 and 2012.

Foreign Currency Translation

Transactions and account balances originally stated in currencies other than the U.S dollar have been translated into U.S. dollars as follows:

·	Revenue and expense items are translated at the average exchange rate for the period in which they are incurred.

·	Non-monetary assets and liabilities at the rate of exchange in effect on the dates the assets were acquired or the liabilities were incurred.

·	Monetary assets and liabilities at the exchange rate at the balance sheet date.

Exchange gains and losses are recorded in operations in the period in which they occur, except for exchange gains and losses related to translation of monetary assets and liabilities associated with mineral properties, which are deferred and included in mineral properties.

Comprehensive income

Comprehensive loss is comprised of net loss and foreign currency translation adjustments for the periods presented.

Related Party Transactions

A related party is generally defined as (i) any person who holds 10% or more of the Company’s securities and their immediate families, (ii) the Company’s management, (iii) someone who directly or indirectly controls, is controlled by or is under common control with the Company, or (iv) anyone who can significantly influence the financial and operating decisions of the Company. A transaction is considered to be a related party transaction when there is a transfer of resources or obligations between related parties. See “Note 6. Related Party Transactions” for further discussion.

Concentration of Risk

Financial instruments that subject the Company to concentrations of credit risk consist primarily of cash and cash equivalents, and accounts receivable. The Company occasionally has cash deposits in excess of federally insured limits. The Company has not experienced any losses related to these balances, and management believes its credit risk to be minimal. Accounts receivable are with the operators of the oil wells in which the Company participates. Given the close working relationship between the operators and the Company, management believes its credit risk is minimal.

Fair Values of Financial Instruments

The Company measures certain financial assets and liabilities at fair value based on the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in on orderly transaction between market participants. The carrying amounts of cash and cash equivalents, accounts receivable, and accounts payable approximate fair value due to the short-term nature of maturity of the instruments.

Recently Issued Accounting Standards Updates

Accounting Standards Update 2012-02: Intangibles - Goodwill and Other (Topic 350): Testing Indefinite-Lived Intangible Assets for Impairment

In July 2012, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2012-02, “Intangibles - Goodwill and Other (Topic 350): Testing Indefinite-Lived Intangible Assets for Impairment,” allowing entities to make a qualitative evaluation about the likelihood of impairment of an indefinite-lived intangible asset to determine whether the quantitative test is required, as opposed to required annual quantitative impairment testing. The update is effective for interim and annual impairment tests performed for fiscal years beginning after September 15, 2012. The adoption of this guidance did not affect the Company's financial condition, results of operations, or cash flows.

3. Oil and Gas Properties

On February 18, 2013, we completed the sale of our working interest in the Onnie Ray #1, Haile #1, Pearce #1 and Stahl #1 oil wells. We entered into an Assignment Agreement with Leexus Oil LLC, the wells operator, whereby the Company assigned its right, title and interest in the oil, gas and mineral leases and the oil and gas wells. Consideration for the assignment was the assumption of all outstanding liabilities and assumption of all future payments for any and all work performed on the wells.

On February 19, 2013, we completed the sale of our working interest in the Cooke #6 well. We entered into an Assignment Agreement with Millennium Petro-Physics, the well operator, whereby we assigned the right, title and interest in the oil, gas and mineral leases and the oil and gas wells. Consideration for the assignment was $3,000 cash.

The carrying amount of the oil and gas properties was $24,127 on the date of disposal. The related asset retirement obligation amounted to $57,532 and liabilities assumed amounted to $12,932. Including the $3,000 cash received, the Company recognized a gain of $49,337 during the three months ended March 31, 2013 as a result of the disposal.

The aggregate amount of capitalized costs relating to crude oil and natural gas producing activities and the aggregate amount of related accumulated depreciation, depletion and amortization at March 31, 2013 and December 31, 2012 were:

	March 31			December 31
	2013			2012				Change ($)
Unproven Properties		$	-		$	537,501			$	(537,501	)
Depreciation and impairment			-			(513,374	)			513,374
Oil and gas properties, net		$	-		$	24,127			$	(24,127	)

There were no material costs incurred in oil and gas property acquisition, exploration and development activities for the three month periods ended March 31, 2013 and 2012.

Due to the 40 to 60 day lead-time for receiving financial results of well operating activities, the effective date of the sale to Leexus Oil LLC and Millennium Petro-Physics was January 1, 2013. Accordingly, we had no revenue, operating expenses or impairment charges for the three month period ended March 31, 2013.

Asset Retirement Obligation

The following table summarizes the activity for the Company’s asset retirement obligations:

	March 31,			December 31,
	2013			2013
Asset retirement obligations, beginning of period	$	57,532		$	55,316
Accretion expense		-			2,216
Liability settled upon sale of properties		(57,532	)		-
Asset retirement obligations, end of period		-			57,532
Less: current portion		-			-
Long-term asset retirement obligations, end of period	$	-		$	57,532

4. Mineral Properties and Exploration Expenses

Foster Township, Sudbury, Ontario, Canada - Fostung Tungsten Property

On June 8, 2011, pursuant to an asset purchase agreement, the Company paid CAD $500,000 in cash for the acquisition of EMC Metals Corp.’s 100% leasehold interest in two mining leases known as the Fostung tungsten property. The Fostung tungsten property consists of two contiguous claim blocks of 30 claims totaling 485 hectors. The nine claims covered by Mining Lease 108592 (“Lease One”) expire on October 31, 2031. The twenty one claims covered by Mining Lease 108847 (“Lease Two”) have been extended by the Ministry of Northern Development, Mines and Forestry (“MNDMF”) through March 31, 2032. The Fostung property is located in Foster Township, Sudbury Mining Division, Ontario, Canada. It is approximately 8 kilometers southeast of the town of Espanola and 70 kilometers west-southwest of the town of Sudbury. An excellent all-weather gravel road extends from Espanola, crossing the property and providing access to the west bay of Lake Panache.

A production bonus in the amount of CAD $500,000 is payable to Breakwater Resources Ltd. by the Company within thirty business days following the commencement of commercial production from the property. A 1% net smelter return royalty on the property is also payable to Breakwater Resources Ltd. by the Company. No capitalized costs have been amortized as of March 31, 2013. The Company did not incur any impairment of these capitalized costs through March 31, 2013.

The Fostung property also consists of four unpatented mining claims, located in Foster Township in the Sudbury Mining Division, Ontario, Canada, comprised of 26 claim units, were recorded in the name of Fostung Resources Ltd. on June 7, 2011. Two of the four mining claim blocks consisting of two contiguous claims are located to the north east of the structural trend in the two contiguous claim blocks of 30 claims referred to in (a) above. Two of the four mining claim blocks consisting of two contiguous claims are located to the south west of the structural trend in the two contiguous claim blocks of 30 claims referred to in (a) above. Each of the four claims has an expiration date of June 7, 2013. The aggregate amount of work required to renew the four claims is CAD $10,400.

5. Commitments and Contingencies

As part of the acquisition of the Fostung tungsten property, located in Foster Township, Sudbury Mining Division, Ontario, Canada, the Company will pay to Breakwater Resources Ltd. (i) a Production Bonus in the amount of CAD $500,000 within thirty (30) business days following the commencement of commercial production from the property and (ii) a 1% Net Smelter Return royalty.

On June 27, 2012, the Company entered into an At-Will Executive Services Agreement (the “Agreement”) with Ms. Janet Bien, pursuant to which Ms. Bien will serve as the Company’s Chief Financial Officer. Pursuant to the Agreement, Ms. Bien will provide the Company with services consistent with that of a Chief Financial Officer on a part-time basis, for which she will be paid a monthly fee of $2,400 and will be reimbursed for any business related expenses. The Agreement is terminable by either the Company or Ms. Bien upon written notice with or without cause.

On February 15, 2013, the Company entered into an Agreement with Kenneth Kirkland, Ph.D. pursuant to which Dr. Kirkland will serve as a member of the Company’s Advisory Board. The Agreement provides for a monthly fee of $2,000. The Agreement may be terminated by either party with a five day notice.

6. Related Party Transactions

On January 12, 2012, Mr. Cacace resigned from the positions of President, Chief Executive Officer, Chief Financial Officer and Director of the Company and Mr. Derek Cooper was appointed to the positions of President, Chief Executive Officer, Chief Financial Officer and Director of the Company. On June 18, 2012, Mr. Derek Cooper resigned as the Company’s President, Chief Executive Officer, Chief Financial Officer and Director. Effective as of June 19, 2012, Mr. Joseph Sierchio, one of the Company’s directors, was appointed as its Acting Interim President and Chief Executive Officer; and effective as of June 27, 2012, Ms. Janet Bien was appointed as the Company’s Chief Financial Officer.

For the three months ended March 31, 2013 and 2012, fees of $7,200 and $9,189 were paid or are due to officers of the Company. Included in accounts payable - related parties at March 31, 2013 is $4,800 (December 31, 2012 - $7,200) for management fees.

For the three month period ended March 31, 2013 and 2012, advisory board fees of $3,000 and $0 were paid to non-officer directors of the Company. Included in accounts payable – related parties at March 31, 2013 is $2,000 (December 31, 2012 - $0) for advisory fees.

For the three months ended March 31, 2013 and 2012, legal fees of $67,090 and $12,744 were paid or are due to a company controlled by our attorney, Mr. Sierchio. Included in accounts payable - related parties at March 31, 2013 is $33,862 (December 31, 2012 - $2,438) for legal fees.

Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations

Forward-Looking Statements

You should read the following discussion and analysis of our financial condition and results of operations together with our financial statements and related notes appearing elsewhere in this Quarterly Report filed on Form 10-Q. This discussion and analysis contains forward-looking statements that involve risks, uncertainties and assumptions. Our actual results may differ materially from those anticipated in these forward-looking statements as a result of many factors, including, but not limited to, those set forth under the heading “Risk Factors and Uncertainties” in our Form 10-K filed with the SEC on April 1, 2013, and elsewhere in this report.

This discussion and analysis should be read in conjunction with the accompanying unaudited interim consolidated financial statements and related notes. The discussion and analysis of the financial condition and results of operations are based upon the unaudited interim consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States. The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires Janus to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of any contingent liabilities at the financial statement date and reported amounts of revenue and expenses during the reporting period. On an on-going basis Janus reviews its estimates and assumptions. The estimates were based on historical experience and other assumptions that Janus believes to be reasonable under the circumstances. Actual results are likely to differ from those estimates under different assumptions or conditions, but Janus does not believe such differences will materially affect our financial position or results of operations. Critical accounting policies, the policies Janus believes are most important to the presentation of its financial statements and require the most difficult, subjective and complex judgments, are outlined below in “Critical Accounting Policies,” and have not changed significantly.

Cautionary Note Regarding Forward-Looking Statements

In addition, certain statements made in this report may constitute “forward-looking statements”. These forward-looking statements involve known or unknown risks, uncertainties and other factors that may cause the actual results, performance, or achievements of Janus to be materially different from any future results, performance or achievements expressed or implied by the forward-looking statements. Except for historical information, the matters set forth herein, which are forward-looking statements, involve certain risks and uncertainties that could cause actual results to differ. Potential risks and uncertainties include, but are not limited to, unexpected changes in business and economic conditions; significant increases or decreases in commodity prices; changes in interest and currency exchange rates; unanticipated grade changes; metallurgy, processing, access, availability of materials, equipment, supplies and water; determination of reserves; results of current and future exploration activities; results of pending and future feasibility studies; joint venture relationships; political or economic instability, either globally or in the countries in which we operate; local and community impacts and issues; timing of receipt of government approvals; accidents and labor disputes; environmental costs and risks; competitive factors, including competition for property acquisitions; and availability of external financing at reasonable rates or at all.

Forward-looking statements can be identified by terminology such as “may,” “will,” “should,” “expects,” “intends,” “plans,” “anticipates,” “believes,” “estimates,” “predicts,” “potential,” “continues” or the negative of these terms or other comparable terminology. Although Janus believes that the expectations reflected in the forward-looking statements contained herein are reasonable, it cannot guarantee future results, levels of activity, performance or achievements. Forward-looking statements are made based on management’s beliefs, estimates, and opinions on the date the statements are made, and Janus undertakes no obligation to update such forward-looking statements if these beliefs, estimates, and opinions should change, except as required by law.

GLOSSARY OF CERTAIN OIL AND GAS TERMS

The following is a description of the meanings of some of the natural gas and oil industry terms used in this filing:

“Operator” refers to the individual or company responsible for the exploration, development and production of an oil or gas well or lease.

“Working interest” refers to the operating interest that gives the owner the right to drill, produce and conduct operating activities on the property and receive a share of production.

GLOSSARY OF CERTAIN MINERAL EXPLORATION TERMS

The following is a description of the meanings of some mineral exploration terms used in this filing:

“Net Smelter Return” (“NSR”) royalties are based on the value of production or net proceeds received by the operator from a smelter or refinery. These proceeds are usually subject to deductions or charges for transportation, insurance, smelting and refining costs as set out in the royalty agreement. For gold royalties, the deductions are generally minimal while for base metal projects, the deductions can be much more substantial. This type of royalty provides cash flow that is free of any operating or capital costs and environmental liabilities. A smaller percentage NSR in a project can effectively equate to the economic value of a larger percentage profit or working interest in the same project.

Overview

Company Overview

We are in the business of location, acquisition, exploration and, if warranted, development of mineral exploration properties.

Advisory Board Appointment

On February 15, 2013, we entered into an Agreement with Kenneth Kirkland, Ph.D. pursuant to which Dr. Kirkland will serve as a member of the Company’s Advisory Board. The Agreement may be terminated by either party with a five day notice.

Mineral Properties

We are currently concentrating our mineral property exploration activities in Canada. We are also examining data relating to the potential acquisition of other mineral exploration properties.

Foster Township, Sudbury, Ontario, Canada – Fostung Tungsten Property

(a)

On June 8, 2011, pursuant to an asset purchase agreement, the Company paid CAD $500,000 in cash for the acquisition of EMC Metals Corp’s. 100% leasehold interest in two mining leases known as the Fostung tungsten property. The Fostung tungsten property consists of two contiguous claim blocks of 30 claims totaling 485 hectors. The nine claims covered by Mining Lease 108592 (“Lease One”) expire on October 31, 2031. The twenty one claims covered by Mining Lease 108847 (“Lease Two”) have been extended by the Ministry of Northern Development, Mines and Forestry (“MNDMF”) through March 31, 2032. The Fostung property is located in Foster Township, Sudbury Mining Division, Ontario, Canada. It is approximately 8 kilometers southeast of the town of Espanola and 70 kilometers west-southwest of the town of Sudbury. An excellent all-weather gravel road extends from Espanola, crossing the property and providing access to the west bay of Lake Panache.

A production bonus in the amount of CAD $500,000 is payable to Breakwater Resources Ltd. by us within thirty business days following the commencement of commercial production from the property. A 1% Net Smelter Return royalty on the property is also payable to Breakwater Resources Ltd. by us. No capitalized costs have been amortized as of March 31, 2013. We did not incur any impairment of these capitalized costs through March 31, 2013.

(b)

Oil and Gas Properties

We pursue oil and gas prospects in partnership with oil and gas companies with exploration, development and production expertise. Prior to February 2013, we had non-operating, minority working interests in properties in La Salle County, Fayette County, Lee County and Frio County, Texas.

Neither we, nor our partners, Leexus Oil LLC and Millennium Petro-Physics (collectively, the “Partners”), had conducted any reserve studies to establish proved reserves associated with the our oil and gas properties during the time we maintained a minority working interest in the properties.

Results of Operations

In February 2013, we completed the sale of our working interests in our oil and gas properties. Due to the 40 to 60 day lead-time for receiving financial results of well operating activities, the effective date of the sale was January 1, 2103. Accordingly, we had no revenue, operating expenses or impairment charges for the three month period ended March 31, 2013.

Exploration expenses were $0 and $3,138 for the three month periods ended March 31, 2013 and 2012. Exploration expenses on the Fostung property are charged to operations as they are incurred.

Our general and administrative expenses consist primarily of personnel costs, legal costs, investor relations costs, accounting costs and other professional and administrative costs. For the three month periods ended March 31, 2013 and 2012, general and administrative expenses were $70,372 and $80,812.

Mineral Property Interests

We have concluded that mineral rights meet the definition of tangible assets. Accordingly, we account for our mineral properties on a cost basis whereby all direct costs, net of pre-production revenue, relative to the acquisition of the properties are capitalized. All sales and option proceeds received are first credited against the costs of the related property, with any excess credited to earnings. Once commercial production has commenced, the net costs of the applicable property will be charged to operations using the unit-of-production method based on estimated proven and probable recoverable reserves. The net costs related to abandoned properties are charged to operations.

Costs of exploring, carrying and retaining unproven properties are charged to operations as incurred until such time that proven reserves are discovered. From that time forward, we will capitalize all costs to the extent that future cash flow from mineral reserves equals or exceeds the costs deferred. The deferred costs will be amortized over the recoverable reserves when a property reaches commercial production. At March 31, 2013, we did not have proven reserves. Exploration activities conducted jointly with others are reflected at our proportionate interest in such activities.

Liquidity and Capital Resources

We currently finance our activities primarily by the private placement of securities. There is no assurance that equity funding will be accessible to us at the times and in the amounts required to fund our activities. There are many conditions beyond our control which have a direct bearing on the level of investor interest in the purchase of Company securities. We may also attempt to generate additional working capital through the operation, development, sale or possible joint venture development of its properties; however, there is no assurance that any such activity will generate funds that will be available for operations. Failure to obtain such additional financing may result in a reduction of our interest in certain properties or an actual foreclosure of our interest. Debt financing has not been used to fund our property acquisitions and exploration activities, and we have no current plans to use debt financing. We do not have “standby” credit facilities, or off-balance sheet arrangements and it does not use hedges or other financial derivatives. We have no agreements or understandings with any person as to additional financing.

We began 2013 with cash and cash equivalents of $513,595. At March 31, 2013, we had cash of $490,050. Total liabilities as of March 31, 2013,were $63,076 (December 31, 2012 - $98,075).

Our unaudited interim consolidated financial statements have been prepared in accordance with generally accepted accounting principles in the United States of America and applicable to a going concern which contemplates the realization of assets and the satisfaction of liabilities and commitments in the normal course of business. Our continuation as a going concern is dependent upon the continued financial support of its shareholders, our ability to obtain necessary equity financing to continue operations, confirmation of our interest in the underlying properties, the attainment of profitable operations and/or realizing proceeds from the sale of one or more of the properties. As discussed in “Note 1” to the consolidated financial statements, we have incurred recurring operating losses since inception and used cash of $26,545 from operating activities in 2013. As at March 31, 2013, we have an accumulated deficit of $4,512,039 and working capital of $426,974, which management believes is sufficient to fund operations through at least the next twelve months, however we intend to raise additional equity (presumably through equity offerings and/or debt borrowing) as the opportunity presents itself.

Our mineral exploration properties have not commenced commercial production.

Cash Flow

Operating activities: We used cash of $26,545 for the three month period ended March 31, 2013 (2012 - $125,697). The following is a breakdown of the cash and non-cash items (i.e. transactions reflected in net loss which do not arise from cash transactions) used for operating activities, aside from the net losses in each period: Impairment and depreciation of $nil (2012 - $331); accretion of asset retirement obligation of $nil (2012 - $729);a non cash gain on the disposal of assets of $49,337 (2012 - $nil); changes in accounts receivable resulted in an increase in cash of $800 (2012 – increase in cash of $6,752); changes in prepaid expenses resulted in an increase in cash of $7,562 (2012 –decrease in cash of $10,200); changes in accounts payable and accrued expenses (including related party) resulted in an increase in cash of $35,465 (2012 –decrease in cash of $40,056) respectively.

Investing Activities: During the three month period ended March 31, 2013, there was $3,000 in cash flows from investing activities (2012 - $nil), respectively.

Financing Activities:

There were no financing activities during 2013 and 2012.

Dividends

We have neither declared nor paid any dividends on our common stock. We intend to retain our earnings to finance growth and expand our operations and do not anticipate paying any dividends on our common stock in the foreseeable future.

Share Capital

At May 15, 2013, we had:

·	Authorized share capital of 200,000,000 (December 31, 2012, – 200,000,000) common shares with par value of $0.00001 each.

·	Authorized share capital of 10,000,000 (December 31, 2012 – 10,000,000) preferred shares with par value of $0.0001 each.

·	63,075,122 common shares were issued and outstanding (December 31, 2012, – 63,075,122).

Market Risk Disclosures

We have not entered into derivative contracts either to hedge existing risks or for speculative purposes during the three months ended March 31, 2013 and the subsequent period to May 15, 2013.

Off-balance Sheet Arrangements and Contractual Obligations

We do not have any off-balance sheet arrangements or contractual obligations at March 31, 2013, and the subsequent period to May 15, 2013, that are likely to have or are reasonably likely to have a material current or future effect on our financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources that have not been disclosed in our consolidated financial statements.

Effects of Inflation and Pricing

The crude oil and natural gas industry is cyclical and the demand for goods and services of crude oil field companies, suppliers and others associated with the industry put extreme pressure on the economic stability and pricing structure within the industry. Typically, as prices for crude oil and natural gas increase, so do all associated costs. Conversely, in a period of declining prices, associated cost declines are likely to lag and may not adjust downward in proportion. Material changes in prices also impact our current revenue stream, estimates of future reserves, borrowing base calculations of bank loans, impairment assessments of crude oil and natural gas properties, and values of properties in purchase and sale transactions. Material changes in prices can impact the value of crude oil and natural gas companies and their ability to raise capital, borrow money and retain personnel. While we do not currently expect business costs to materially increase, higher prices for crude oil and natural gas could result in increases in the costs of materials, services and personnel.

Environmental Compliance

Our current and future exploration and development activities, as well as our future mining and processing operations and oil and gas operations, are subject to various federal, state and local laws and regulations in the countries in which we conduct our activities. These laws and regulations govern the protection of the environment, prospecting, development, production, taxes, labor standards, occupational health, mine safety, toxic substances and other matters. We expect to be able to comply with those laws and do not believe that compliance will have a material adverse effect on our competitive position. We intend to obtain all licenses and permits required by all applicable regulatory agencies in connection with our mining operations and exploration activities. We intend to maintain standards of environmental compliance consistent with regulatory requirements.

We have an obligation to reclaim our properties after the surface has been disturbed by exploration methods at the site.

Critical Accounting Policies

See “Note 2. Significant Accounting Policies” in the Notes to the Consolidated Financial Statements included herein.

Related Party Transactions

Our proposed business may raise potential conflicts of interests between certain of our officers and directors and us. In the event that such a conflict of interest arises at a meeting of our directors, a director who has such a conflict will abstain from voting for or against the approval of such participation or such terms. In appropriate cases, we will establish a special committee of independent directors to review a matter in which several directors, or management, may have a conflict. From time to time, several companies may participate in the acquisition, exploration and development of natural resource properties thereby allowing for their participation in larger programs, involvement in a greater number of programs and reduction of the financial exposure with respect to any one program. It may also occur that a particular company will assign all or a portion of its interest in a particular program to another of these companies due to the financial position of the company making the assignment.

In determining whether we will participate in a particular program and the interest therein to be acquired by it, the directors will primarily consider the potential benefits to us, the degree of risk to which we may be exposed and our financial position at that time. Other than as indicated, we have no other procedures or mechanisms to deal with conflicts of interest. We are not aware of the existence of any conflict of interest as described herein.

For the three month period ended March 31, 2013 and 2012, advisory board fees of $3,000 and $nil were paid to non-officer directors of the Company. Included in accounts payable – related parties at March 31, 2013 is $2,000 (December 31, 2012 - $nil) for advisory fees.

For the three months ended March 31, 2013 and 2012, legal fees of $67,090 and $12,744 were paid or are due to a law firm of which Mr. Sierchio, our Acting Interim President and Chief Executive Officer, is the managing partner. Included in accounts payable - related parties at March 31, 2013 is $33,862 (December 31, 2012 - $2,438) for legal fees.

These transactions are in the normal course of operations and are measured at the exchange amount, which is the amount of consideration established and agreed to by the related parties.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Not applicable.

Item 4. Controls and Procedures

Disclosure Controls and Procedures

At the end of the period covered by this Quarterly Report on Form 10-Q for the three month period ended March 31, 2013, an evaluation was carried out under the supervision of and with the participation of our management, including the Chief Executive Officer (“CEO”) and Chief Financial Officer (“CFO”), of the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rule 13a-15(e) and Rule 15d-15(e) under the Exchange Act). Based on that evaluation the CEO and the CFO have concluded that as of the end of the period covered by this report, our disclosure controls and procedures are effective in ensuring that: (i) information required to be disclosed by us in reports that it files or submits to the SEC under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in applicable rules and forms and (ii) material information required to be disclosed in our reports filed under the Exchange Act is accumulated and communicated to our management, including our CEO and CFO, as appropriate, to allow for accurate and timely decisions regarding required disclosure.

Changes in Internal Control over Financial Reporting

During the period covered by this report, there were no changes to internal control over financial reporting that materially affected or are reasonably likely to materially affect our internal control over financial reporting.

PART II – OTHER INFORMATION

Item 1. Legal Proceedings

None

Item 1A. Risk Factors

There are no material changes from the risk factors previously disclosed in Janus’ Form 10-K filed on April 1, 2013, with the SEC.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

None

Item 6. Exhibits

Exhibit Index

Exhibit No.		Description of Exhibit

3.1		Articles of incorporation (exhibit 3.1). S-8 filing dated October 3, 2003.

3.2		Bylaws (exhibit 3.2). S-8 filing dated October 3, 2003.

10.1		Assignment Agreement between Janus Resources, Inc. and Leexus Oil LLC dated as of February 18, 2013.*

10.2		Assignment Agreement between Janus Resources, Inc. and Millennium Petro-Physics, Inc. dated as of February 19, 2013.*

31.1		Certification of Principal Executive Officer Pursuant to Rule 13a-14 of the Securities Exchange Act of 1934, As Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.*

31.2		Certification of Principal Financial Officer Pursuant to Rule 13a-14 of the Securities Exchange Act of 1934, As Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.*

32.1		Certification of Principal Executive Officer and Principal Financial Officer Pursuant to 18 U.S.C. Section 1350, As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.*

101.INS		XBRL Instance Document

101.SCH		XBRL Taxonomy Extension - Schema Document

101.CAL		XBRL Taxonomy Extension - Calculation Linkbase Document

101.DEF		XBRL Taxonomy Extension - Definition Linkbase Document

101.LAB		XBRL Taxonomy Extension - Label Linkbase Document

101.PRE		XBRL Taxonomy Extension - Presentation Linkbase Document

_________

*Filed here within.

SIGNATURES

Pursuant to the requirements of Sections 13 or 15 (d) of the Securities and Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

	Janus Resources, Inc.
	(Registrant)

Date: May 15, 2013	By:	/s/ Joseph Sierchio
		Name: Joseph Sierchio
		Title: Acting Interim President and Chief Executive Officer
		(Principal Executive Officer)


Date: May 15, 2013	By:	/s/ Janet Bien
		Name: Janet Bien
		Title: Chief Financial Officer
		(Principal Financial Officer)

EX-10.1 2 jani_ex101.htm ASSIGNMENT AGREEMENT jani_ex101.htm

EXHIBIT 10.1

ASSIGNMENT AGREEMENT

THIS ASSIGNMENT AGREEMENT (the “Agreement”) is entered into as of February 18, 2013, by and between Janus Resources, Inc. (formerly Entheos Technologies, Inc.) (“Janus”) a Nevada corporation with a principal place of business located at 430 Park Avenue, New York, New York 10022 and Leexus Oil LLC (“Leexus”) a Texas limited liability corporation with a principal place of business located at P.O. Box 726, Giddings, Texas 78942. Assignor and Assignee may hereinafter be referred to individually as a “Party” or collectively as the “Parties.”

RECITALS:

WHEREAS, on September 9, 2008, Janus entered into a participation agreement with Leexus pursuant to which Janus purchased a 20% working interest and 15% net revenue interest to the Haile#1 Well located in Frio County, Texas (the “Haile Well”) from Leexus as further set forth on Exhibit A hereto;

WHEREAS, on September 9, 2008, Janus entered into a participation agreement with Leexus pursuant to which Janus purchased a 20% working interest and 15% net revenue interest to the Onnie Ray#1 Well located in Lee County, Texas (the “Onnie Ray Well”) from Leexus as further set forth on Exhibit B hereto;

WHEREAS, on September 9, 2008, Janus entered into a participation agreement with Leexus pursuant to which Janus purchased a 20% working interest and 15% net revenue interest to the Stahl#1 Well located in Fayette County, Texas (the “Stahl Well”) from Leexus as further set forth on Exhibit C hereto;

WHEREAS, on October 15, 2008, Janus entered into a participation agreement with Leexus pursuant to which Assignor purchased a 20% working interest and 15% net revenue interest to the Pearce#1 Well located in Frio County, Texas (the “Pearce Well”) from Leexus as further set forth on Exhibit D hereto (the Haile Well, Onnie Ray Well, Stahl Well and Pearce Well are hereinafter referred to collectively as the “Wells”); and

WHEREAS, Janus desires to sell to Leexus, and Leexus desires to purchase from Janus, all of Janus’ interest in the Wells on the terms and conditions set forth in this Agreement.

NOW, THEREFORE, for good and valuable consideration, the sufficiency and receipt is hereby acknowledged by the Parties, the Parties agree as follows:

1. Payment. As payment for the Wells, Leexus shall (i) assume and be liable for the $11,366.78 owed by Janus to Leexus for work performed on the Wells as of the date of this Agreement and (ii) assume and be liable for all future payments for any and all work performed on the Wells.

2. Assignment. Upon Janus’ receipt of a “Settlement Statement” from Leexus showing that there are not outstanding funds due to Leexus from Janus for the Wells, Janus will execute an Assignment and Bill of Sale conveying Janus’ interests in the Wells to Leexus. It is understood and agreed by the Parties that the interests in the Wells to be assigned in and to the Wells shall be made on an “as-is, where-is” basis and Janus expressly disclaims any warranty of any kind. Janus will provide Leexus a copy of the Assignment and Bill of Sale for its review and consideration prior to execution of this Agreement. Acceptance and execution of this Agreement by Leexus shall be deemed acceptance of the Assignment and Bill of Sale form.

3. Warranty Disclaimer. Janus makes no warranty of title, express or implied, with respect to the Wells or any leasehold or other right(s) acquired hereunder. Leexus’ interest in and to the Wells will be acquired on an “as-is, where-is” basis.

4. Entire Agreement. This Agreement constitutes the entire agreement by and between Janus and Leexus and may not be altered or amended except in writing signed by both Parties.

5. Governing Law. This Agreement shall be governed by the laws of the State of New York.

[REMAINDER OF PAGE INTENTIONALLY LEFT BLANK]

EX-10.2 3 jani_ex102.htm ASSIGNMENT AGREEMENT jani_ex102.htm

EXHIBIT 10.2

ASSIGNMENT AGREEMENT

THIS ASSIGNMENT AGREEMENT (this “Agreement”) is entered into as of February 19, 2013, by and between Janus Resources, Inc. (formerly Entheos Technologies, Inc.) (“Janus”) a Nevada corporation with a principal place of business located at 430 Park Avenue, New York, New York 10022 and Millennium Petro-Physics, Inc. (“Millennium”) a Texas corporation with a principal place of business located at 600 Leopard Street, 600 Leopard Street, 600 Building, Suite 1104, Corpus Christi, Texas 78401. Janus and Millennium may hereinafter be referred to individually as a “Party” or collectively as the “Parties.”

RECITALS:

WHEREAS, on September 1, 2008, Bayshore Exploration L.L.C., a Texas limited liability company, assigned a 21.75% of 8/8ths working interest and a 16.3125% of 8/8th net revenue interst to Janus to the Cooke #6 Well located in La Salle County, Texas (the “Cooke Well”) as further set forth on Exhibit A hereto;

WHEREAS, Janus desires to assign its interest in the Cooke Well to Millennium, and Millennium desires to accept the assignment of the Cooke Well from Janus, on the terms and conditions set forth in this Agreement.

NOW THEREFORE, for good and valuable consideration, the receipt and sufficiency are hereby acknowledged by the Parties, the Parties hereby agree as follows:

6. Payment. As payment for the assignment of the Cooke Well, Millennium shall pay to Janus the sum of $3,000 (the “Payment Amount”) by check or bank wire.

7. Assignment. Within five (5) business days of Janus’s receipt of the Payment Amount, Janus shall forward an executed Assignment and Bill of Sale, substantially in the form of Appendix A hereto, conveying Janus’ interests in the Cooke Well to Millennium, Millennium shall forward to Janus. It is understood and agreed by the Parties that the interest in the Cooke Well to be assigned in and to the Cooke Well shall be made on an “as-is, where-is” basis and Janus expressly disclaims any warranty of any kind.

8. Warranty Disclaimer. Janus makes no warranty of title, express or implied, with respect to the Cooke Well or any leasehold or other right(s) acquired hereunder. Millennium’s interest in and to the Cooke Well will be acquired on an “as-is, where-is” basis.

9. Entire Agreement. This Agreement constitutes the entire agreement by and between Janus and Millennium and may not be altered or amended except in writing signed by both Parties.

10. Governing Law. This Agreement shall be governed by the laws of the State of New York.

[REMAINDER OF PAGE INTENTIONALLY LEFT BLANK]

EX-31.1 4 jani_ex311.htm CERTIFICATION jani_ex311.htm

EXHIBIT 31.1

CERTIFICATION PURSUANT TO RULE 13A-14(A) OR RULE 15D-14(A)

UNDER THE SECURITIES EXCHANGE ACT OF 1934, AS AMENDED

I, Joseph Sierchio, certify that:

1.	I have reviewed this quarterly report on Form 10-Q of Janus Resources, Inc.;

2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e) ) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

	(a)	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

	(b)	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

	(c)	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

	(d)	Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.	The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

	(a)	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

	(b)	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 15, 2013	By:	/s/ Joseph Sierchio
	Name:	Joseph Sierchio
	Title:	Acting Interim President and Chief Executive Officer (Principal Executive Officer)

EX-31.2 5 jani_ex312.htm CERTIFICATION jani_ex312.htm

EXHIBIT 31.2

CERTIFICATION PURSUANT TO RULE 13A-14(A) OR RULE 15D-14(A)

UNDER THE SECURITIES EXCHANGE ACT OF 1934, AS AMENDED

I, Janet Bien, certify that:

1.	I have reviewed this quarterly report on Form 10-Q of Janus Resources, Inc.;

2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

	(a)	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

	(b)	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

	(c)	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

	(d)	Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.	The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

	(a)	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

	(b)	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 15, 2013	By:	/s/ Janet Bien
	Name:	Janet Bien
	Title:	Chief Financial Officer
		(Principal Financial Officer)

EX-32.1 6 jani_ex321.htm CERTIFICATION jani_ex321.htm

EXHIBIT 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (Section 1350 of Chapter 63 of Title 18 of the United States Code), the undersigned officers of Janus Resources, Inc. (the “Company”) do hereby certify with respect to the Quarterly Report of the Company on Form 10-Q for the period ended March 31, 2013 (the “Report”) that:

(i) the Report filed by the Company fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(ii) The information contained in that Report fairly presents, in all material respects, the financial condition and results of operations of the Company on the dates and for the periods presented therein.

	JANUS RESOURCES, INC.

Date: May 15, 2013	By:	/s/ Joseph Sierchio
	Name:	Joseph Sierchio
	Title:	Acting Interim President and Chief Executive Officer (Principal Executive Officer)

Date: May 15, 2013	By:	/s/ Janet Bien
	Name:	Janet Bien
	Title:	Chief Financial Officer (Principal Financial Officer)

This certification accompanies this Report pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 and shall not be deemed filed by the Company for purposes of Section 18 of the Securities Exchange Act of 1934, as amended. A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

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Janus Resources, Inc. (formerly Entheos Technologies, Inc.) (the Company, we, us, and our) is in the business of locating, acquiring, exploring and, if warranted, developing both mineral exploration properties and oil and gas properties. The Company pursues oil and gas prospects in partnership with oil and gas companies with exploration, development and production expertise. Prior to February 2013 the Company had non-operating, minority working interests in oil and gas properties. The properties were sold on February 18 and 19, 2013. On June 8, 2011, the Company completed the acquisition of the Fostung tungsten property, located in Foster Township, Sudbury, Ontario, Canada.   The Companys general business strategy is to acquire mineral properties and oil and gas properties either directly or through the acquisition of operating entities. Its continued operations and the recoverability of property costs are dependent upon the existence of economically recoverable mineral and oil and gas reserves, the confirmation of its interest in the underlying properties, its ability to obtain necessary financing to complete development, and future profitable production.   The Company has recently incurred net operating losses and operating cash flow deficits. The Companys accumulated deficit is $4,512,039 as of March 31, 2013. It may continue to incur losses from operations and operating cash flow deficits in the future. Management believes that the Companys cash and cash equivalent balances, anticipated cash flows from operations and other external sources of credit will be sufficient to meet its cash requirements for the next twelve months if not further. The future of the Company after March 2014 will depend in large part on its ability to successfully generate cash flows from operations and raise capital from external sources to fund operations.

Basis of Presentation and Principles of Accounting   The interim consolidated financial statements included herein have been prepared by the Company, without audit, in accordance with the rules and regulations of the Securities and Exchange Commission (SEC) pursuant to Part 210 of Regulation S-X. Certain information and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America (US GAAP) have been condensed or omitted pursuant to such SEC rules and regulations, although the Company believes that the disclosures included are adequate to make the information presented not misleading.   In managements opinion, the unaudited consolidated financial statements contained herein reflect all adjustments, consisting solely of normal recurring items, which are necessary for the fair presentation of our financial position, results of operations, and cash flows on a basis consistent with that of our prior audited consolidated financial statements. The Company has evaluated information about subsequent events that became available to them through the date the financial statements were issued. This information relates to events, transactions or changes in circumstances that would require us to adjust the amounts reported in the financial statements or to disclose information about those events, transactions or changes in circumstances. However, the results of operations for interim periods may not be indicative of results to be expected for the full fiscal year. Therefore, these financial statements should be read in conjunction with the Companys audited consolidated financial statements including the notes thereto for the year ended December 31, 2012, which may be found under the Companys profile on EDGAR.   The accounting policies followed by the Company are set out in Note 2 to the audited consolidated financial statements for the year ended December 31, 2012 and have been consistently followed in the preparation of these consolidated interim financial statements.   Principles of Consolidation   These interim consolidated financial statements have been prepared in accordance with US GAAP and include the accounts of the Company and its wholly-owned subsidiaries, Fostung Resources, Limited (Fostung) and Entheos Energy, Inc. (Entheos). Collectively, they are referred to herein as the Company. All significant intercompany transactions and balances have been eliminated. Fostung was formed on incorporated on May 10, 2011, in Ontario Canada. Entheos was incorporated under the laws of the State of Nevada on October 5, 2000.   Applicable Accounting Guidance   Any reference in these notes to applicable accounting guidance is meant to refer to the authoritative non-governmental United States GAAP as found in the Financial Accounting Standards Boards (FASB) Accounting Standards Codification (ASC).   Accounting Estimates   The preparation of consolidated 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 reported amounts of assets and liabilities and the reported amounts of revenues and expenses during the reporting period. Significant areas requiring the use of management estimates include the determination of impairment of mineral properties, valuation allowances for future income tax assets, fair value of non-cash stock-based compensation, common stock warrants and reclamation and environmental obligations. Actual results, as determined by future events, may differ from these estimates. Managements judgments and estimates in these areas are based on information available from both internal and external sources, including engineers, geologists, consultants and historical experience in similar matters.   Cash and Cash Equivalents   The Company considers all highly liquid instruments purchased with an original maturity of three months or less to be cash equivalents. The Company did not have any cash equivalents at March 31, 2013 and December 31, 2012.   Mineral Properties   The Company has concluded that mineral rights meet the definition of tangible assets. Accordingly, the Company accounts for its mineral properties on a cost basis whereby all direct costs, net of pre-production revenue, relative to the acquisition of the properties are capitalized. All sales and option proceeds received are first credited against the costs of the related property, with any excess credited to earnings. Once commercial production has commenced, the net costs of the applicable property will be charged to operations using the unit-of-production method based on estimated proven and probable recoverable reserves. The net costs related to abandoned properties are charged to operations.   Costs of exploring, carrying and retaining unproven properties are charged to operations as incurred until such time that proven reserves are discovered. From that time forward, the Company will capitalize all costs to the extent that future cash flow from mineral reserves equals or exceeds the costs deferred. The deferred costs will be amortized over the recoverable reserves when a property reaches commercial production. As at March 31, 2013 and December 31, 2012, the Company did not have proven reserves. Exploration activities conducted jointly with others are reflected at the Company's proportionate interest in such activities.   Full Cost Method of Accounting for Oil and Gas Properties   The Company has elected to utilize the full cost method of accounting for its oil and gas activities. In accordance with the full cost method of accounting, all costs associated with acquisition, exploration, and development of oil and gas reserves, including directly related overhead costs and related asset retirement costs are capitalized.   All capitalized costs of oil and gas properties, including the estimated future costs to develop proved reserves, are amortized on the unit-of-production method using estimates of proved reserves once proved reserves are determined to exist. The Company did not establish proved reserves for oil and gas properties during the periods presented and as such did not record amortization.   Oil and gas properties without estimated proved reserves are assessed for impairment at each reporting date. As a result of managements impairment analysis, the Company recorded an impairment loss of $nil and $331 during the three month periods ended March 31, 2013 and 2012, respectively.   Sales of oil and gas properties are accounted for as adjustments of capitalized costs with no gain or loss recognized, unless such adjustments would significantly alter the relationship between capitalized costs and proved reserves of oil and gas, in which case the gain or loss is recognized in income. On February 18, 2013 and February 19, 2013 the Company sold its interests in all of its oil and gas properties. During the three month period ended March 31, 2013, a gain of $49,337 was recognized in income as there are no longer any oil and gas capitalized costs.   Asset Retirement Obligation   The Company records the fair value of the liability for closure and removal costs associated with the legal obligations upon retirement or removal of any tangible long-lived assets by recording the fair value of the liability during the period in which it was incurred. The associated asset retirement costs are capitalized as part of the carrying amount of the long-lived asset. The increase in carrying value of a property associated with the capitalization of an asset retirement obligation is included in oil and gas properties in the balance sheets. The Companys asset retirement obligation consists of costs related to the plugging of wells, removal of facilities and equipment and site restoration on its oil and gas properties. The asset retirement liability is allocated to operating expense using a systematic and rational method. Asset retirement obligations amounted to $nil and $57,532 at March 31, 2013 and December 31, 2012, respectively. See Note 3. Oil and Gas Properties for further discussion.   Impairment of Long-Lived Assets   The Company reviews and evaluates its long-lived assets for impairment at each balance sheet date and documents such impairment testing. The tests include an evaluation of the assets and events or changes in circumstances that would indicate that the related carrying amounts may not be recoverable.   Oil and gas properties are subject to a ceiling test which basically limits capitalized costs to the sum of the estimated future net revenues from proved reserves, discounted at 10% per annum to present value, based on current economic and operating conditions, adjusted for related income tax effects.   Mineral properties in the exploration stage are monitored for impairment based on factors such as the Companys continued right to explore the area, exploration reports, assays, technical reports, drill results and the Companys continued plans to fund exploration programs on the property, whether sufficient work has been performed to indicate that the carrying amount of the mineral property cost carried forward as an asset will not be fully recovered, even though a viable mine has been discovered.   The tests for long-lived assets in the exploration, development or producing stage that would have a value beyond proven and probable reserves would be monitored for impairment based on factors such as current market value of the mineral property and results of exploration, future asset utilization, business climate, mineral prices and future undiscounted cash flows expected to result from the use of the related assets. Recoverability of assets to be held and used is measured by a comparison of the carrying amount of an asset to the estimated future net undiscounted cash flows expected to be generated by the asset, including evaluating its reserves beyond proven and probable amounts.   The Companys policy is to record an impairment loss in the period when it is determined that the carrying amount of the asset may not be recoverable either due to impairment or by abandonment of the property. The impairment loss is calculated as the amount by which the carrying amount of the asset exceeds its fair value. While the Company incurred losses from operations, these losses have not been in excess of planned expenditures on the specific mineral properties in order to ultimately realize their value.   Oil and Gas Revenue Recognition   The Company recognizes oil and gas revenues when oil and gas production is sold to a purchaser at a fixed or determinable price, when delivery has occurred and title has transferred, and if collectability of the revenue is probable. Delivery occurs and title is transferred when production has been delivered to a purchasers pipeline or truck. As a result of the numerous requirements necessary to gather information from purchasers or various measurement locations, calculate volumes produced, perform field and wellhead allocations, distribute and disburse funds to various working interest partners and royalty owners, the collection of revenues from oil and gas production may take up to 45 days following the month of production. Therefore, the Company may make accruals for revenues and accounts receivable based on estimates of its share of production. Since the settlement process may take 30 to 60 days following the month of actual production, its financial results may include estimates of production and revenues for the related time period. The Company will record any differences between the actual amounts ultimately received and the original estimates in the period they become finalized.   Income Taxes   The Company recognizes income taxes on an accrual basis based on tax position taken or expected to be taken in our tax returns. A tax position is defined as a position in a previously filed tax return or a position expected to be taken in a future tax filing that is reflected in measuring current or deferred income tax assets and liabilities. Tax positions are recognized only when it is more likely than not (i.e., likelihood of greater than 50%), based on technical merits, that the position would be sustained upon examination by taxing authorities. Tax positions that meet the more likely than not threshold are measured using a probability-weighted approach as the largest amount of tax benefit that is greater than 50% likely of being realized upon settlement. Income taxes are accounted for using an asset and liability approach that requires the recognition of deferred tax assets and liabilities for the expected future tax consequences of events that have been recognized in our financial statements or tax returns. A valuation allowance is established to reduce deferred tax assets if all, or some portion, of such assets will more than likely not be realized. Should they occur, our policy is to classify interest and penalties related to tax positions as interest expense. Since our inception, no such interest or penalties have been incurred.   Earnings (Loss) Per Share   The Company presents both basic and diluted earnings per share (EPS) amounts. Basic EPS is calculated by dividing net income by the weighted average number of common shares outstanding during the period presented. Diluted EPS amounts are based upon the weighted average number of common and common equivalent shares outstanding during the period presented. There were no dilutive shares outstanding for the three month period ended March 31, 2013 and 2012.   Foreign Currency Translation   Transactions and account balances originally stated in currencies other than the U.S dollar have been translated into U.S. dollars as follows:   <table cellspacing="0" cellpadding="0" style="width: 100%"> <tr style="vertical-align: top"> <td style="width: 48px; font: 10pt Times New Roman, Times, Serif; text-align: right">·  </td> <td style="font: 10pt Times New Roman, Times, Serif; text-align: justify">Revenue and expense items are translated at the average exchange rate for the period in which they are incurred.</td></tr> <tr style="vertical-align: top"> <td style="font: 10pt Times New Roman, Times, Serif; text-align: right">·  </td> <td style="font: 10pt Times New Roman, Times, Serif; text-align: justify">Non-monetary assets and liabilities at the rate of exchange in effect on the dates the assets were acquired or the liabilities were incurred.</td></tr> </table> <table cellspacing="0" cellpadding="0" style="width: 100%"> <tr style="vertical-align: top"> <td style="width: 48px; font: 10pt Times New Roman, Times, Serif; text-align: right">·  </td> <td style="font: 10pt Times New Roman, Times, Serif">Monetary assets and liabilities at the exchange rate at the balance sheet date.</td></tr> </table>   Exchange gains and losses are recorded in operations in the period in which they occur, except for exchange gains and losses related to translation of monetary assets and liabilities associated with mineral properties, which are deferred and included in mineral properties.   Comprehensive income   Comprehensive loss is comprised of net loss and foreign currency translation adjustments for the periods presented.   Related Party Transactions   A related party is generally defined as (i) any person who holds 10% or more of the Companys securities and their immediate families, (ii) the Companys management, (iii) someone who directly or indirectly controls, is controlled by or is under common control with the Company, or (iv) anyone who can significantly influence the financial and operating decisions of the Company. A transaction is considered to be a related party transaction when there is a transfer of resources or obligations between related parties. See Note 6. Related Party Transactions for further discussion.   Concentration of Risk   Financial instruments that subject the Company to concentrations of credit risk consist primarily of cash and cash equivalents, and accounts receivable. The Company occasionally has cash deposits in excess of federally insured limits. The Company has not experienced any losses related to these balances, and management believes its credit risk to be minimal. Accounts receivable are with the operators of the oil wells in which the Company participates. Given the close working relationship between the operators and the Company, management believes its credit risk is minimal.   Fair Values of Financial Instruments   The Company measures certain financial assets and liabilities at fair value based on the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in on orderly transaction between market participants. The carrying amounts of cash and cash equivalents, accounts receivable, and accounts payable approximate fair value due to the short-term nature of maturity of the instruments.   Recently Issued Accounting Standards Updates   Accounting Standards Update 2012-02: Intangibles - Goodwill and Other (Topic 350): Testing Indefinite-Lived Intangible Assets for Impairment   In July 2012, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2012-02, Intangibles - Goodwill and Other (Topic 350): Testing Indefinite-Lived Intangible Assets for Impairment, allowing entities to make a qualitative evaluation about the likelihood of impairment of an indefinite-lived intangible asset to determine whether the quantitative test is required, as opposed to required annual quantitative impairment testing. The update is effective for interim and annual impairment tests performed for fiscal years beginning after September 15, 2012. The adoption of this guidance did not affect the Company's financial condition, results of operations, or cash flows.

On February 18, 2013, we completed the sale of our working interest in the Onnie Ray #1, Haile #1, Pearce #1 and Stahl #1 oil wells. We entered into an Assignment Agreement with Leexus Oil LLC, the wells operator, whereby the Company assigned its right, title and interest in the oil, gas and mineral leases and the oil and gas wells. Consideration for the assignment was the assumption of all outstanding liabilities and assumption of all future payments for any and all work performed on the wells.   On February 19, 2013, we completed the sale of our working interest in the Cooke #6 well. We entered into an Assignment Agreement with Millennium Petro-Physics, the well operator, whereby we assigned the right, title and interest in the oil, gas and mineral leases and the oil and gas wells. Consideration for the assignment was $3,000 cash.   The carrying amount of the oil and gas properties was $24,127 on the date of disposal. The related asset retirement obligation amounted to $57,532 and liabilities assumed amounted to $12,932. Including the $3,000 cash received, the Company recognized a gain of $49,337 during the three months ended March 31, 2013 as a result of the disposal.   The aggregate amount of capitalized costs relating to crude oil and natural gas producing activities and the aggregate amount of related accumulated depreciation, depletion and amortization at March 31, 2013 and December 31, 2012 were:   <table cellspacing="0" cellpadding="0" style="font: 10pt Times New Roman, Times, Serif; width: 100%"> <tr style="vertical-align: bottom; background-color: white"> <td> </td> <td colspan="3" style="text-align: center">March 31</td> <td nowrap="nowrap"> </td> <td colspan="3" style="text-align: center">December 31</td> <td nowrap="nowrap"> </td> <td colspan="3"> </td> <td nowrap="nowrap"> </td></tr> <tr style="vertical-align: bottom; background-color: white"> <td> </td> <td colspan="3" style="border-bottom: black 1.5pt solid; text-align: center">2013</td> <td nowrap="nowrap"> </td> <td colspan="3" style="border-bottom: black 1.5pt solid; text-align: center">2012</td> <td nowrap="nowrap"> </td> <td colspan="3" style="border-bottom: black 1.5pt solid; text-align: center">Change ($)</td> <td nowrap="nowrap"> </td></tr> <tr style="vertical-align: bottom; background-color: #CCEEFF"> <td style="width: 62%">Unproven Properties</td> <td style="width: 1%; text-align: right"> </td> <td style="width: 1%">$</td> <td style="width: 9%; text-align: right">-</td> <td nowrap="nowrap" style="width: 1%"> </td> <td style="width: 1%; text-align: right"> </td> <td style="width: 1%">$</td> <td style="width: 9%; text-align: right">537,501</td> <td nowrap="nowrap" style="width: 1%"> </td> <td style="width: 1%; text-align: right"> </td> <td style="width: 1%">$</td> <td style="width: 11%; text-align: right">(537,501</td> <td nowrap="nowrap" style="width: 1%">)</td></tr> <tr style="vertical-align: bottom; background-color: white"> <td>Depreciation and impairment</td> <td style="text-align: right"> </td> <td style="border-bottom: black 1.5pt solid"> </td> <td style="border-bottom: black 1.5pt solid; text-align: right">-</td> <td nowrap="nowrap"> </td> <td style="text-align: right"> </td> <td style="border-bottom: black 1.5pt solid"> </td> <td style="border-bottom: black 1.5pt solid; text-align: right">(513,374 </td> <td nowrap="nowrap">)</td> <td style="text-align: right"> </td> <td> </td> <td style="text-align: right">513,374</td> <td nowrap="nowrap"> </td></tr> <tr style="vertical-align: bottom; background-color: #CCEEFF"> <td>Oil and gas properties, net</td> <td style="text-align: right"> </td> <td style="border-bottom: black 2.25pt double">$</td> <td style="border-bottom: black 2.25pt double; text-align: right">-</td> <td nowrap="nowrap"> </td> <td style="text-align: right"> </td> <td style="border-bottom: black 2.25pt double">$</td> <td style="border-bottom: black 2.25pt double; text-align: right">24,127</td> <td nowrap="nowrap"> </td> <td style="text-align: right"> </td> <td style="border-bottom: black 2.25pt double">$</td> <td style="border-bottom: black 2.25pt double; text-align: right">(24,127</td> <td nowrap="nowrap">)</td></tr> </table>   There were no material costs incurred in oil and gas property acquisition, exploration and development activities for the three month periods ended March 31, 2013 and 2012   Due to the 40 to 60 day lead-time for receiving financial results of well operating activities, the effective date of the sale to Leexus Oil LLC and Millennium Petro-Physics was January 1, 2013. Accordingly, we had no revenue, operating expenses or impairment charges for the three month period ended March 31, 2013.   Asset Retirement Obligation   The following table summarizes the activity for the Companys asset retirement obligations:   <table cellspacing="0" cellpadding="0" style="font: 10pt Times New Roman, Times, Serif; width: 100%"> <tr style="vertical-align: bottom; background-color: white"> <td> </td> <td> </td> <td colspan="2" style="text-align: center">March 31,</td> <td nowrap="nowrap"> </td> <td> </td> <td colspan="2" style="text-align: center">December 31,</td> <td nowrap="nowrap"> </td></tr> <tr style="vertical-align: bottom; background-color: white"> <td> </td> <td> </td> <td colspan="2" style="border-bottom: black 1.5pt solid; text-align: center">2013</td> <td nowrap="nowrap"> </td> <td> </td> <td colspan="2" style="border-bottom: black 1.5pt solid; text-align: center">2013</td> <td nowrap="nowrap"> </td></tr> <tr style="vertical-align: bottom; background-color: #CCEEFF"> <td style="width: 76%">Asset retirement obligations, beginning of period</td> <td style="width: 1%; text-align: right"> </td> <td style="width: 1%">$</td> <td style="width: 9%; text-align: right">57,532</td> <td nowrap="nowrap" style="width: 1%"> </td> <td style="width: 1%; text-align: right"> </td> <td style="width: 1%">$</td> <td style="width: 9%; text-align: right">55,316</td> <td nowrap="nowrap" style="width: 1%"> </td></tr> <tr style="vertical-align: bottom; background-color: white"> <td>     Accretion expense</td> <td style="text-align: right"> </td> <td> </td> <td style="text-align: right">-</td> <td nowrap="nowrap"> </td> <td style="text-align: right"> </td> <td> </td> <td style="text-align: right">2,216</td> <td nowrap="nowrap"> </td></tr> <tr style="vertical-align: bottom; background-color: #CCEEFF"> <td>     Liability settled upon sale of properties</td> <td style="text-align: right"> </td> <td style="border-bottom: black 1.5pt solid"> </td> <td style="border-bottom: black 1.5pt solid; text-align: right">(57,532</td> <td nowrap="nowrap">)</td> <td style="text-align: right"> </td> <td style="border-bottom: black 1.5pt solid"> </td> <td style="border-bottom: black 1.5pt solid; text-align: right">-</td> <td nowrap="nowrap"> </td></tr> <tr style="vertical-align: bottom; background-color: white"> <td>Asset retirement obligations, end of period</td> <td style="text-align: right"> </td> <td style="border-bottom: black 1.5pt solid"> </td> <td style="border-bottom: black 1.5pt solid; text-align: right">-</td> <td nowrap="nowrap"> </td> <td style="text-align: right"> </td> <td style="border-bottom: black 1.5pt solid"> </td> <td style="border-bottom: black 1.5pt solid; text-align: right">57,532</td> <td nowrap="nowrap"> </td></tr> <tr style="vertical-align: bottom; background-color: #CCEEFF"> <td>Less: current portion</td> <td style="text-align: right"> </td> <td style="border-bottom: black 1.5pt solid"> </td> <td style="border-bottom: black 1.5pt solid; text-align: right">-</td> <td nowrap="nowrap"> </td> <td style="text-align: right"> </td> <td style="border-bottom: black 1.5pt solid"> </td> <td style="border-bottom: black 1.5pt solid; text-align: right">-</td> <td nowrap="nowrap"> </td></tr> <tr style="vertical-align: bottom; background-color: white"> <td>Long-term asset retirement obligations, end of period</td> <td style="text-align: right"> </td> <td style="border-bottom: black 2.25pt double">$</td> <td style="border-bottom: black 2.25pt double; text-align: right">-</td> <td nowrap="nowrap"> </td> <td style="text-align: right"> </td> <td style="border-bottom: black 2.25pt double">$</td> <td style="border-bottom: black 2.25pt double; text-align: right">57,532</td> <td nowrap="nowrap"> </td></tr> </table>

Foster Township, Sudbury, Ontario, Canada - Fostung Tungsten Property   <table cellspacing="0" cellpadding="0" style="width: 100%"> <tr style="vertical-align: top"> <td style="width: 7%; font: 10pt Times New Roman, Times, Serif; text-align: center">a)</td> <td style="width: 93%"> On June 8, 2011, pursuant to an asset purchase agreement, the Company paid CAD $500,000 in cash for the acquisition of EMC Metals Corp.s 100% leasehold interest in two mining leases known as the Fostung tungsten property. The Fostung tungsten property consists of two contiguous claim blocks of 30 claims totaling 485 hectors. The nine claims covered by Mining Lease 108592 (Lease One) expire on October 31, 2031. The twenty one claims covered by Mining Lease 108847 (Lease Two) have been extended by the Ministry of Northern Development, Mines and Forestry (MNDMF) through March 31, 2032. The Fostung property is located in Foster Township, Sudbury Mining Division, Ontario, Canada. It is approximately 8 kilometers southeast of the town of Espanola and 70 kilometers west-southwest of the town of Sudbury. An excellent all-weather gravel road extends from Espanola, crossing the property and providing access to the west bay of Lake Panache.   A production bonus in the amount of CAD $500,000 is payable to Breakwater Resources Ltd. by the Company within thirty business days following the commencement of commercial production from the property. A 1% net smelter return royalty on the property is also payable to Breakwater Resources Ltd. by the Company. No capitalized costs have been amortized as of March 31, 2013. The Company did not incur any impairment of these capitalized costs through March 31, 2013.</td></tr> </table>    <table cellspacing="0" cellpadding="0" style="width: 100%"> <tr style="vertical-align: top"> <td style="width: 7%; font: 10pt Times New Roman, Times, Serif; text-align: center">b)</td> <td style="width: 93%; font: 10pt Times New Roman, Times, Serif; text-align: justify">The Fostung property also consists of four unpatented mining claims, located in Foster Township in the Sudbury Mining Division, Ontario, Canada, comprised of 26 claim units, were recorded in the name of Fostung Resources Ltd. on June 7, 2011. Two of the four mining claim blocks consisting of two contiguous claims are located to the north east of the structural trend in the two contiguous claim blocks of 30 claims referred to in (a) above. Two of the four mining claim blocks consisting of two contiguous claims are located to the south west of the structural trend in the two contiguous claim blocks of 30 claims referred to in (a) above. Each of the four claims has an expiration date of June 7, 2013. The aggregate amount of work required to renew the four claims is CAD $10,400.</td></tr> </table>

As part of the acquisition of the Fostung tungsten property, located in Foster Township, Sudbury Mining Division, Ontario, Canada, the Company will pay to Breakwater Resources Ltd. (i) a Production Bonus in the amount of CAD $500,000 within thirty (30) business days following the commencement of commercial production from the property and (ii) a 1% Net Smelter Return royalty.   On June 27, 2012, the Company entered into an At-Will Executive Services Agreement (the Agreement) with Ms. Janet Bien, pursuant to which Ms. Bien will serve as the Companys Chief Financial Officer. Pursuant to the Agreement, Ms. Bien will provide the Company with services consistent with that of a Chief Financial Officer on a part-time basis, for which she will be paid a monthly fee of $2,400 and will be reimbursed for any business related expenses. The Agreement is terminable by either the Company or Ms. Bien upon written notice with or without cause.   On February 15, 2013, the Company entered into an Agreement with Kenneth Kirkland, Ph.D. pursuant to which Dr. Kirkland will serve as a member of the Companys Advisory Board. The Agreement provides for a monthly fee of $2,000. The Agreement may be terminated by either party with a five day notice.

On January 12, 2012, Mr. Cacace resigned from the positions of President, Chief Executive Officer, Chief Financial Officer and Director of the Company and Mr. Derek Cooper was appointed to the positions of President, Chief Executive Officer, Chief Financial Officer and Director of the Company. On June 18, 2012, Mr. Derek Cooper resigned as the Companys President, Chief Executive Officer, Chief Financial Officer and Director. Effective as of June 19, 2012, Mr. Joseph Sierchio, one of the Companys directors, was appointed as its Acting Interim President and Chief Executive Officer; and effective as of June 27, 2012, Ms. Janet Bien was appointed as the Companys Chief Financial Officer.   For the three months ended March 31, 2013 and 2012, fees of $7,200 and $9,189 were paid or are due to officers of the Company. Included in accounts payable - related parties at March 31, 2013 is $4,800 (December 31, 2012 - $7,200) for management fees.   For the three month period ended March 31, 2013 and 2012, advisory board fees of $3,000 and $0 were paid to non-officer directors of the Company. Included in accounts payable related parties at March 31, 2013 is $2,000 (December 31, 2012 - $0) for advisory fees.   For the three months ended March 31, 2013 and 2012, legal fees of $67,090 and $12,744 were paid or are due to a company controlled by our attorney, Mr. Sierchio. Included in accounts payable - related parties at March 31, 2013 is $33,862 (December 31, 2012 - $2,438) for legal fees.

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The interim consolidated financial statements included herein have been prepared by the Company, without audit, in accordance with the rules and regulations of the Securities and Exchange Commission (SEC) pursuant to Part 210 of Regulation S-X. Certain information and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America (US GAAP) have been condensed or omitted pursuant to such SEC rules and regulations, although the Company believes that the disclosures included are adequate to make the information presented not misleading.   In managements opinion, the unaudited consolidated financial statements contained herein reflect all adjustments, consisting solely of normal recurring items, which are necessary for the fair presentation of our financial position, results of operations, and cash flows on a basis consistent with that of our prior audited consolidated financial statements. The Company has evaluated information about subsequent events that became available to them through the date the financial statements were issued. This information relates to events, transactions or changes in circumstances that would require us to adjust the amounts reported in the financial statements or to disclose information about those events, transactions or changes in circumstances. However, the results of operations for interim periods may not be indicative of results to be expected for the full fiscal year. Therefore, these financial statements should be read in conjunction with the Companys audited consolidated financial statements including the notes thereto for the year ended December 31, 2012, which may be found under the Companys profile on EDGAR.   The accounting policies followed by the Company are set out in Note 2 to the audited consolidated financial statements for the year ended December 31, 2012 and have been consistently followed in the preparation of these consolidated interim financial statements.

These interim consolidated financial statements have been prepared in accordance with US GAAP and include the accounts of the Company and its wholly-owned subsidiaries, Fostung Resources, Limited (Fostung) and Entheos Energy, Inc. (Entheos). Collectively, they are referred to herein as the Company. All significant intercompany transactions and balances have been eliminated. Fostung was formed on incorporated on May 10, 2011, in Ontario Canada. Entheos was incorporated under the laws of the State of Nevada on October 5, 2000.

Any reference in these notes to applicable accounting guidance is meant to refer to the authoritative non-governmental United States GAAP as found in the Financial Accounting Standards Boards (FASB) Accounting Standards Codification (ASC).

The preparation of consolidated 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 reported amounts of assets and liabilities and the reported amounts of revenues and expenses during the reporting period. Significant areas requiring the use of management estimates include the determination of impairment of mineral properties, valuation allowances for future income tax assets, fair value of non-cash stock-based compensation, common stock warrants and reclamation and environmental obligations. Actual results, as determined by future events, may differ from these estimates. Managements judgments and estimates in these areas are based on information available from both internal and external sources, including engineers, geologists, consultants and historical experience in similar matters.

The Company considers all highly liquid instruments purchased with an original maturity of three months or less to be cash equivalents. The Company did not have any cash equivalents at March 31, 2013 and December 31, 2012.

The Company has concluded that mineral rights meet the definition of tangible assets. Accordingly, the Company accounts for its mineral properties on a cost basis whereby all direct costs, net of pre-production revenue, relative to the acquisition of the properties are capitalized. All sales and option proceeds received are first credited against the costs of the related property, with any excess credited to earnings. Once commercial production has commenced, the net costs of the applicable property will be charged to operations using the unit-of-production method based on estimated proven and probable recoverable reserves. The net costs related to abandoned properties are charged to operations.   Costs of exploring, carrying and retaining unproven properties are charged to operations as incurred until such time that proven reserves are discovered. From that time forward, the Company will capitalize all costs to the extent that future cash flow from mineral reserves equals or exceeds the costs deferred. The deferred costs will be amortized over the recoverable reserves when a property reaches commercial production. As at March 31, 2013 and December 31, 2012, the Company did not have proven reserves. Exploration activities conducted jointly with others are reflected at the Company's proportionate interest in such activities.

The Company has elected to utilize the full cost method of accounting for its oil and gas activities. In accordance with the full cost method of accounting, all costs associated with acquisition, exploration, and development of oil and gas reserves, including directly related overhead costs and related asset retirement costs are capitalized.   All capitalized costs of oil and gas properties, including the estimated future costs to develop proved reserves, are amortized on the unit-of-production method using estimates of proved reserves once proved reserves are determined to exist. The Company did not establish proved reserves for oil and gas properties during the periods presented and as such did not record amortization.   Oil and gas properties without estimated proved reserves are assessed for impairment at each reporting date. As a result of managements impairment analysis, the Company recorded an impairment loss of $nil and $331 during the three month periods ended March 31, 2013 and 2012, respectively.   Sales of oil and gas properties are accounted for as adjustments of capitalized costs with no gain or loss recognized, unless such adjustments would significantly alter the relationship between capitalized costs and proved reserves of oil and gas, in which case the gain or loss is recognized in income. On February 18, 2013 and February 19, 2013 the Company sold its interests in all of its oil and gas properties. During the three month period ended March 31, 2013, a gain of $49,337 was recognized in income as there are no longer any oil and gas capitalized costs.

The Company records the fair value of the liability for closure and removal costs associated with the legal obligations upon retirement or removal of any tangible long-lived assets by recording the fair value of the liability during the period in which it was incurred. The associated asset retirement costs are capitalized as part of the carrying amount of the long-lived asset. The increase in carrying value of a property associated with the capitalization of an asset retirement obligation is included in oil and gas properties in the balance sheets. The Companys asset retirement obligation consists of costs related to the plugging of wells, removal of facilities and equipment and site restoration on its oil and gas properties. The asset retirement liability is allocated to operating expense using a systematic and rational method. Asset retirement obligations amounted to $nil and $57,532 at March 31, 2013 and December 31, 2012, respectively. See Note 3. Oil and Gas Properties for further discussion.

The Company reviews and evaluates its long-lived assets for impairment at each balance sheet date and documents such impairment testing. The tests include an evaluation of the assets and events or changes in circumstances that would indicate that the related carrying amounts may not be recoverable.   Oil and gas properties are subject to a ceiling test which basically limits capitalized costs to the sum of the estimated future net revenues from proved reserves, discounted at 10% per annum to present value, based on current economic and operating conditions, adjusted for related income tax effects.   Mineral properties in the exploration stage are monitored for impairment based on factors such as the Companys continued right to explore the area, exploration reports, assays, technical reports, drill results and the Companys continued plans to fund exploration programs on the property, whether sufficient work has been performed to indicate that the carrying amount of the mineral property cost carried forward as an asset will not be fully recovered, even though a viable mine has been discovered.   The tests for long-lived assets in the exploration, development or producing stage that would have a value beyond proven and probable reserves would be monitored for impairment based on factors such as current market value of the mineral property and results of exploration, future asset utilization, business climate, mineral prices and future undiscounted cash flows expected to result from the use of the related assets. Recoverability of assets to be held and used is measured by a comparison of the carrying amount of an asset to the estimated future net undiscounted cash flows expected to be generated by the asset, including evaluating its reserves beyond proven and probable amounts.    The Companys policy is to record an impairment loss in the period when it is determined that the carrying amount of the asset may not be recoverable either due to impairment or by abandonment of the property. The impairment loss is calculated as the amount by which the carrying amount of the asset exceeds its fair value. While the Company incurred losses from operations, these losses have not been in excess of planned expenditures on the specific mineral properties in order to ultimately realize their value.

The Company recognizes oil and gas revenues when oil and gas production is sold to a purchaser at a fixed or determinable price, when delivery has occurred and title has transferred, and if collectability of the revenue is probable. Delivery occurs and title is transferred when production has been delivered to a purchasers pipeline or truck. As a result of the numerous requirements necessary to gather information from purchasers or various measurement locations, calculate volumes produced, perform field and wellhead allocations, distribute and disburse funds to various working interest partners and royalty owners, the collection of revenues from oil and gas production may take up to 45 days following the month of production. Therefore, the Company may make accruals for revenues and accounts receivable based on estimates of its share of production. Since the settlement process may take 30 to 60 days following the month of actual production, its financial results may include estimates of production and revenues for the related time period. The Company will record any differences between the actual amounts ultimately received and the original estimates in the period they become finalized.

The Company recognizes income taxes on an accrual basis based on tax position taken or expected to be taken in our tax returns. A tax position is defined as a position in a previously filed tax return or a position expected to be taken in a future tax filing that is reflected in measuring current or deferred income tax assets and liabilities. Tax positions are recognized only when it is more likely than not (i.e., likelihood of greater than 50%), based on technical merits, that the position would be sustained upon examination by taxing authorities. Tax positions that meet the more likely than not threshold are measured using a probability-weighted approach as the largest amount of tax benefit that is greater than 50% likely of being realized upon settlement. Income taxes are accounted for using an asset and liability approach that requires the recognition of deferred tax assets and liabilities for the expected future tax consequences of events that have been recognized in our financial statements or tax returns. A valuation allowance is established to reduce deferred tax assets if all, or some portion, of such assets will more than likely not be realized. Should they occur, our policy is to classify interest and penalties related to tax positions as interest expense. Since our inception, no such interest or penalties have been incurred.

The Company presents both basic and diluted earnings per share (EPS) amounts. Basic EPS is calculated by dividing net income by the weighted average number of common shares outstanding during the period presented. Diluted EPS amounts are based upon the weighted average number of common and common equivalent shares outstanding during the period presented. There were no dilutive shares outstanding for the three month period ended March 31, 2013 and 2012.

Transactions and account balances originally stated in currencies other than the U.S dollar have been translated into U.S. dollars as follows:   <table cellspacing="0" cellpadding="0" style="width: 100%"> <tr style="vertical-align: top"> <td style="width: 48px; font: 10pt Times New Roman, Times, Serif; text-align: right">·  </td> <td style="font: 10pt Times New Roman, Times, Serif; text-align: justify">Revenue and expense items are translated at the average exchange rate for the period in which they are incurred.</td></tr> <tr style="vertical-align: top"> <td style="font: 10pt Times New Roman, Times, Serif; text-align: right">·  </td> <td style="font: 10pt Times New Roman, Times, Serif; text-align: justify">Non-monetary assets and liabilities at the rate of exchange in effect on the dates the assets were acquired or the liabilities were incurred.</td></tr> </table> <table cellspacing="0" cellpadding="0" style="width: 100%"> <tr style="vertical-align: top"> <td style="width: 48px; font: 10pt Times New Roman, Times, Serif; text-align: right">·  </td> <td style="font: 10pt Times New Roman, Times, Serif; text-align: justify">Monetary assets and liabilities at the exchange rate at the balance sheet date.</td></tr> </table>   Exchange gains and losses are recorded in operations in the period in which they occur, except for exchange gains and losses related to translation of monetary assets and liabilities associated with mineral properties, which are deferred and included in mineral properties.

Comprehensive loss is comprised of net loss and foreign currency translation adjustments for the periods presented.

A related party is generally defined as (i) any person who holds 10% or more of the Companys securities and their immediate families, (ii) the Companys management, (iii) someone who directly or indirectly controls, is controlled by or is under common control with the Company, or (iv) anyone who can significantly influence the financial and operating decisions of the Company. A transaction is considered to be a related party transaction when there is a transfer of resources or obligations between related parties. See Note 6. Related Party Transactions for further discussion.

Financial instruments that subject the Company to concentrations of credit risk consist primarily of cash and cash equivalents, and accounts receivable. The Company occasionally has cash deposits in excess of federally insured limits. The Company has not experienced any losses related to these balances, and management believes its credit risk to be minimal. Accounts receivable are with the operators of the oil wells in which the Company participates. Given the close working relationship between the operators and the Company, management believes its credit risk is minimal.

The Company measures certain financial assets and liabilities at fair value based on the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in on orderly transaction between market participants. The carrying amounts of cash and cash equivalents, accounts receivable, and accounts payable approximate fair value due to the short-term nature of maturity of the instruments.

Accounting Standards Update 2012-02: Intangibles - Goodwill and Other (Topic 350): Testing Indefinite-Lived Intangible Assets for Impairment   In July 2012, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2012-02, Intangibles - Goodwill and Other (Topic 350): Testing Indefinite-Lived Intangible Assets for Impairment, allowing entities to make a qualitative evaluation about the likelihood of impairment of an indefinite-lived intangible asset to determine whether the quantitative test is required, as opposed to required annual quantitative impairment testing. The update is effective for interim and annual impairment tests performed for fiscal years beginning after September 15, 2012. The adoption of this guidance did not affect the Company's financial condition, results of operations, or cash flows.

The aggregate amount of capitalized costs relating to crude oil and natural gas producing activities and the aggregate amount of related accumulated depreciation, depletion and amortization at March 31, 2013 and December 31, 2012 were:   <table cellspacing="0" cellpadding="0" style="font: 10pt Times New Roman, Times, Serif; width: 100%"> <tr style="vertical-align: bottom; background-color: white"> <td> </td> <td colspan="3" style="text-align: center">March 31</td> <td nowrap="nowrap"> </td> <td colspan="3" style="text-align: center">December 31</td> <td nowrap="nowrap"> </td> <td colspan="3"> </td> <td nowrap="nowrap"> </td></tr> <tr style="vertical-align: bottom; background-color: white"> <td> </td> <td colspan="3" style="border-bottom: black 1.5pt solid; text-align: center">2013</td> <td nowrap="nowrap"> </td> <td colspan="3" style="border-bottom: black 1.5pt solid; text-align: center">2012</td> <td nowrap="nowrap"> </td> <td colspan="3" style="border-bottom: black 1.5pt solid; text-align: center">Change ($)</td> <td nowrap="nowrap"> </td></tr> <tr style="vertical-align: bottom; background-color: #CCEEFF"> <td style="width: 67%">Unproven Properties</td> <td style="width: 1%; text-align: right"> </td> <td style="width: 1%">$</td> <td style="width: 8%; text-align: right">-</td> <td nowrap="nowrap" style="width: 1%"> </td> <td style="width: 1%; text-align: right"> </td> <td style="width: 1%">$</td> <td style="width: 8%; text-align: right">537,501</td> <td nowrap="nowrap" style="width: 1%"> </td> <td style="width: 1%; text-align: right"> </td> <td style="width: 1%">$</td> <td style="width: 8%; text-align: right">(537,501</td> <td nowrap="nowrap" style="width: 1%">)</td></tr> <tr style="vertical-align: bottom; background-color: white"> <td>Depreciation and impairment</td> <td style="text-align: right"> </td> <td style="border-bottom: black 1.5pt solid"> </td> <td style="border-bottom: black 1.5pt solid; text-align: right">-</td> <td nowrap="nowrap"> </td> <td style="text-align: right"> </td> <td style="border-bottom: black 1.5pt solid"> </td> <td style="border-bottom: black 1.5pt solid; text-align: right">(513,374 </td> <td nowrap="nowrap">)</td> <td style="text-align: right"> </td> <td> </td> <td style="text-align: right">513,374</td> <td nowrap="nowrap"> </td></tr> <tr style="vertical-align: bottom; background-color: #CCEEFF"> <td>Oil and gas properties, net</td> <td style="text-align: right"> </td> <td style="border-bottom: black 2.25pt double">$</td> <td style="border-bottom: black 2.25pt double; text-align: right">-</td> <td nowrap="nowrap"> </td> <td style="text-align: right"> </td> <td style="border-bottom: black 2.25pt double">$</td> <td style="border-bottom: black 2.25pt double; text-align: right">24,127</td> <td nowrap="nowrap"> </td> <td style="text-align: right"> </td> <td style="border-bottom: black 2.25pt double">$</td> <td style="border-bottom: black 2.25pt double; text-align: right">(24,127</td> <td nowrap="nowrap">)</td></tr> </table>

The following table summarizes the activity for the Companys asset retirement obligations:   <table cellspacing="0" cellpadding="0" style="font: 10pt Times New Roman, Times, Serif; width: 100%"> <tr style="vertical-align: bottom; background-color: white"> <td> </td> <td> </td> <td colspan="2" style="text-align: center">March 31,</td> <td nowrap="nowrap"> </td> <td> </td> <td colspan="2" style="text-align: center">December 31,</td> <td nowrap="nowrap"> </td></tr> <tr style="vertical-align: bottom; background-color: white"> <td> </td> <td> </td> <td colspan="2" style="border-bottom: black 1.5pt solid; text-align: center">2013</td> <td nowrap="nowrap"> </td> <td> </td> <td colspan="2" style="border-bottom: black 1.5pt solid; text-align: center">2013</td> <td nowrap="nowrap"> </td></tr> <tr style="vertical-align: bottom; background-color: #CCEEFF"> <td style="width: 78%">Asset retirement obligations, beginning of period</td> <td style="width: 1%; text-align: right"> </td> <td style="width: 1%">$</td> <td style="width: 8%; text-align: right">57,532</td> <td nowrap="nowrap" style="width: 1%"> </td> <td style="width: 1%; text-align: right"> </td> <td style="width: 1%">$</td> <td style="width: 8%; text-align: right">55,316</td> <td nowrap="nowrap" style="width: 1%"> </td></tr> <tr style="vertical-align: bottom; background-color: white"> <td>     Accretion expense</td> <td style="text-align: right"> </td> <td> </td> <td style="text-align: right">-</td> <td nowrap="nowrap"> </td> <td style="text-align: right"> </td> <td> </td> <td style="text-align: right">2,216</td> <td nowrap="nowrap"> </td></tr> <tr style="vertical-align: bottom; background-color: #CCEEFF"> <td>     Liability settled upon sale of properties</td> <td style="text-align: right"> </td> <td style="border-bottom: black 1.5pt solid"> </td> <td style="border-bottom: black 1.5pt solid; text-align: right">(57,532</td> <td nowrap="nowrap">)</td> <td style="text-align: right"> </td> <td style="border-bottom: black 1.5pt solid"> </td> <td style="border-bottom: black 1.5pt solid; text-align: right">-</td> <td nowrap="nowrap"> </td></tr> <tr style="vertical-align: bottom; background-color: white"> <td>Asset retirement obligations, end of period</td> <td style="text-align: right"> </td> <td style="border-bottom: black 1.5pt solid"> </td> <td style="border-bottom: black 1.5pt solid; text-align: right">-</td> <td nowrap="nowrap"> </td> <td style="text-align: right"> </td> <td style="border-bottom: black 1.5pt solid"> </td> <td style="border-bottom: black 1.5pt solid; text-align: right">57,532</td> <td nowrap="nowrap"> </td></tr> <tr style="vertical-align: bottom; background-color: #CCEEFF"> <td>Less: current portion</td> <td style="text-align: right"> </td> <td style="border-bottom: black 1.5pt solid"> </td> <td style="border-bottom: black 1.5pt solid; text-align: right">-</td> <td nowrap="nowrap"> </td> <td style="text-align: right"> </td> <td style="border-bottom: black 1.5pt solid"> </td> <td style="border-bottom: black 1.5pt solid; text-align: right">-</td> <td nowrap="nowrap"> </td></tr> <tr style="vertical-align: bottom; background-color: white"> <td>Long-term asset retirement obligations, end of period</td> <td style="text-align: right"> </td> <td style="border-bottom: black 2.25pt double">$</td> <td style="border-bottom: black 2.25pt double; text-align: right">-</td> <td nowrap="nowrap"> </td> <td style="text-align: right"> </td> <td style="border-bottom: black 2.25pt double">$</td> <td style="border-bottom: black 2.25pt double; text-align: right">57,532</td> <td nowrap="nowrap"> </td></tr> </table>

-537501

57532

55316

57532

-57532

331

7200

9189

3000

67090

12744

331

2216

513374

5462236

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6053

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Significant Accounting Policies

3 Months Ended

Mar. 31, 2013

Significant Accounting Policies

Note 2. Significant Accounting Policies

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Applicable Accounting Guidance

Accounting Estimates

Cash and Cash Equivalents

Mineral Properties

Full Cost Method of Accounting for Oil and Gas Properties

Asset Retirement Obligation

Impairment of Long-Lived Assets

Oil and Gas Revenue Recognition

Income Taxes

Earnings (Loss) Per Share

Foreign Currency Translation

Transactions and account balances originally stated in currencies other than the U.S dollar have been translated into U.S. dollars as follows:

·	Revenue and expense items are translated at the average exchange rate for the period in which they are incurred.
·	Non-monetary assets and liabilities at the rate of exchange in effect on the dates the assets were acquired or the liabilities were incurred.

·	Monetary assets and liabilities at the exchange rate at the balance sheet date.

Comprehensive income

Comprehensive loss is comprised of net loss and foreign currency translation adjustments for the periods presented.

Related Party Transactions

Concentration of Risk

Fair Values of Financial Instruments

Recently Issued Accounting Standards Updates

Accounting Standards Update 2012-02: Intangibles - Goodwill and Other (Topic 350): Testing Indefinite-Lived Intangible Assets for Impairment

In July 2012, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2012-02, “Intangibles - Goodwill and Other (Topic 350): Testing Indefinite-Lived Intangible Assets for Impairment,” allowing entities to make a qualitative evaluation about the likelihood of impairment of an indefinite-lived intangible asset to determine whether the quantitative test is required, as opposed to required annual quantitative impairment testing. The update is effective for interim and annual impairment tests performed for fiscal years beginning after September 15, 2012. The adoption of this guidance did not affect the Company's financial condition, results of operations, or cash flows.

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Organization, Nature and Continuance of Operations
3 Months Ended

Mar. 31, 2013

Organization Nature And Continuance Of Operations

Note 1. Organization, Nature and Continuance of Operations
Janus Resources, Inc. (formerly Entheos Technologies, Inc.) (the “Company”, “we”, “us”, and “our”) is in the business of locating, acquiring, exploring and, if warranted, developing both mineral exploration properties and oil and gas properties. The Company pursues oil and gas prospects in partnership with oil and gas companies with exploration, development and production expertise. Prior to February 2013 the Company had non-operating, minority working interests in oil and gas properties. The properties were sold on February 18 and 19, 2013. On June 8, 2011, the Company completed the acquisition of the Fostung tungsten property, located in Foster Township, Sudbury, Ontario, Canada.

The Company’s general business strategy is to acquire mineral properties and oil and gas properties either directly or through the acquisition of operating entities. Its continued operations and the recoverability of property costs are dependent upon the existence of economically recoverable mineral and oil and gas reserves, the confirmation of its interest in the underlying properties, its ability to obtain necessary financing to complete development, and future profitable production.

The Company has recently incurred net operating losses and operating cash flow deficits. The Company’s accumulated deficit is $4,512,039 as of March 31, 2013. It may continue to incur losses from operations and operating cash flow deficits in the future. Management believes that the Company’s cash and cash equivalent balances, anticipated cash flows from operations and other external sources of credit will be sufficient to meet its cash requirements for the next twelve months if not further. The future of the Company after March 2014 will depend in large part on its ability to successfully generate cash flows from operations and raise capital from external sources to fund operations.

Organization, Nature and Continuance of Operations	3 Months Ended
Mar. 31, 2013
Organization Nature And Continuance Of Operations
Note 1. Organization, Nature and Continuance of Operations	Janus Resources, Inc. (formerly Entheos Technologies, Inc.) (the “Company”, “we”, “us”, and “our”) is in the business of locating, acquiring, exploring and, if warranted, developing both mineral exploration properties and oil and gas properties. The Company pursues oil and gas prospects in partnership with oil and gas companies with exploration, development and production expertise. Prior to February 2013 the Company had non-operating, minority working interests in oil and gas properties. The properties were sold on February 18 and 19, 2013. On June 8, 2011, the Company completed the acquisition of the Fostung tungsten property, located in Foster Township, Sudbury, Ontario, Canada. The Company’s general business strategy is to acquire mineral properties and oil and gas properties either directly or through the acquisition of operating entities. Its continued operations and the recoverability of property costs are dependent upon the existence of economically recoverable mineral and oil and gas reserves, the confirmation of its interest in the underlying properties, its ability to obtain necessary financing to complete development, and future profitable production. The Company has recently incurred net operating losses and operating cash flow deficits. The Company’s accumulated deficit is $4,512,039 as of March 31, 2013. It may continue to incur losses from operations and operating cash flow deficits in the future. Management believes that the Company’s cash and cash equivalent balances, anticipated cash flows from operations and other external sources of credit will be sufficient to meet its cash requirements for the next twelve months if not further. The future of the Company after March 2014 will depend in large part on its ability to successfully generate cash flows from operations and raise capital from external sources to fund operations.

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CONSOLIDATED BALANCE SHEETS (USD $)

Mar. 31, 2013

Dec. 31, 2012

Current assets

Cash and cash equivalents $ 490,050 $ 513,595

Accounts receivable 800

Prepaid expenses 7,562

Total current assets 490,050 521,957

Oil and gas properties

Unproven properties 537,501

Accumulated depreciation, depletion, amortization and impairment (513,374)

Oil and gas properties, net 24,127

Mineral properties 519,750 519,750

Total assets 1,009,800 1,065,834

Current liabilities

Accounts payable and accrued liabilities 22,415 30,905

Accounts payable - related parties 40,661 9,638

Total current liabilities 63,076 40,543

Asset retirement obligation 0 57,532

Total liabilities 63,076 98,075

STOCKHOLDERS' EQUITY

Preferred stock: $0.0001 par value: Authorized: 10,000,000 shares, Issued and outstanding: nil

Common stock: $0.00001 par value: Authorized: 200,000,000 shares, Issued and outstanding: 63,075,122 shares (2012: 63,075,122) 631 631

Additional paid-in capital 5,462,236 5,462,236

Accumulated deficit (4,512,039) (4,491,004)

Accumulated other comprehensive loss (4,104) (4,104)

Total stockholders' equity 946,724 967,759

Total liabilities and stockholders' equity $ 1,009,800 $ 1,065,834

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CONSOLIDATED STATEMENT STOCKHOLDER’S EQUITY (unaudited) (USD $)

Common Stock [Member]

Additional Paid In Capital [Member]

Accumulated (deficit)

Accumulated other comprehensive (loss)

Total

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Beginning Balance, Shares at Dec. 31, 2011 63,075,122

Net loss (243,959) (243,959)

Ending Balance, Amount at Dec. 31, 2012 631 5,462,236 (4,491,004) (4,104) 967,759

Ending Balance, Shares at Dec. 31, 2012 63,075,122

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Ending Balance, Amount at Mar. 31, 2013 $ 631 $ 5,462,236 $ (4,512,039) $ (4,104) $ 946,724

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CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited) (USD $)
3 Months Ended

Mar. 31, 2013

Mar. 31, 2012

Cash flows from operating activities

Net loss $ (21,035) $ (83,253)

Impairment and depreciation 331

Accretion of asset retirement obligation 729

Gain on disposal of oil and gas properties (49,337)

Changes in operating assets and liabilities:

Decrease (increase) in receivables 800 6,752

Decrease (increase) in prepaid expenses 7,562 (10,200)

(Decrease) increase in accounts payable and accrued liabilities including related party payables 35,465 (40,056)

Net cash flows from operating activities (26,545) (125,697)

Cash flows from investing activities

Proceeds from disposal of oil and gas properties 3,000

Net cash flows from investing activities 3,000

Effect of exchange rate changes on cash and cash equivalents (769)

Decrease in cash and cash equivalents (23,545) (126,466)

Cash and cash equivalents, beginning of period 513,595 787,771

Cash and cash equivalents, end of period 490,050 661,305

Supplemental disclosure of cash flow information:

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Income tax paid in cash

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Exploration expenses (including prospecting) related to oil and gas producing entities and would be included in operating expenses of that entity. Costs incurred in identifying areas that may warrant examination and in examining specific areas that are considered to have prospects of containing oil and gas reserves, including costs of drilling exploratory wells and exploratory-type stratigraphic test wells. Exploration costs may be incurred both before acquiring the related property (sometimes referred to in part as prospecting costs) and after acquiring the property. Principal types of exploration costs, which include depreciation and applicable operating costs of support equipment and facilities and other costs of exploration activities, are: (i) Costs of topographical, geographical and geophysical studies, rights of access to properties to conduct those studies, and salaries and other expenses of geologists, geophysical crews, and others conducting those studies. Collectively, these are sometimes referred to as geological and geophysical or "G&G" costs. (ii) Costs of carrying and retaining undeveloped properties, such as delay rentals, ad valorem taxes on properties, legal costs for title defense, and the maintenance of land and lease records. (iii) Dry hole contributions and bottom hole contributions. (iv) Costs of drilling and equipping exploratory wells. (v) Costs of drilling exploratory-type stratigraphic test wells.

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Commitments and Contingencies
3 Months Ended

Mar. 31, 2013

Commitments And Contingencies

Note 5. Commitments and Contingencies
As part of the acquisition of the Fostung tungsten property, located in Foster Township, Sudbury Mining Division, Ontario, Canada, the Company will pay to Breakwater Resources Ltd. (i) a Production Bonus in the amount of CAD $500,000 within thirty (30) business days following the commencement of commercial production from the property and (ii) a 1% Net Smelter Return royalty.

On June 27, 2012, the Company entered into an At-Will Executive Services Agreement (the “Agreement”) with Ms. Janet Bien, pursuant to which Ms. Bien will serve as the Company’s Chief Financial Officer. Pursuant to the Agreement, Ms. Bien will provide the Company with services consistent with that of a Chief Financial Officer on a part-time basis, for which she will be paid a monthly fee of $2,400 and will be reimbursed for any business related expenses. The Agreement is terminable by either the Company or Ms. Bien upon written notice with or without cause.

On February 15, 2013, the Company entered into an Agreement with Kenneth Kirkland, Ph.D. pursuant to which Dr. Kirkland will serve as a member of the Company’s Advisory Board. The Agreement provides for a monthly fee of $2,000. The Agreement may be terminated by either party with a five day notice.

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Mineral Properties and Exploration Expenses
3 Months Ended

Mar. 31, 2013

Mineral Properties And Exploration Expenses

Note 4. Mineral Properties and Exploration Expenses
Foster Township, Sudbury, Ontario, Canada - Fostung Tungsten Property

a)
On June 8, 2011, pursuant to an asset purchase agreement, the Company paid CAD $500,000 in cash for the acquisition of EMC Metals Corp.’s 100% leasehold interest in two mining leases known as the Fostung tungsten property. The Fostung tungsten property consists of two contiguous claim blocks of 30 claims totaling 485 hectors. The nine claims covered by Mining Lease 108592 (“Lease One”) expire on October 31, 2031. The twenty one claims covered by Mining Lease 108847 (“Lease Two”) have been extended by the Ministry of Northern Development, Mines and Forestry (“MNDMF”) through March 31, 2032. The Fostung property is located in Foster Township, Sudbury Mining Division, Ontario, Canada. It is approximately 8 kilometers southeast of the town of Espanola and 70 kilometers west-southwest of the town of Sudbury. An excellent all-weather gravel road extends from Espanola, crossing the property and providing access to the west bay of Lake Panache.

A production bonus in the amount of CAD $500,000 is payable to Breakwater Resources Ltd. by the Company within thirty business days following the commencement of commercial production from the property. A 1% net smelter return royalty on the property is also payable to Breakwater Resources Ltd. by the Company. No capitalized costs have been amortized as of March 31, 2013. The Company did not incur any impairment of these capitalized costs through March 31, 2013.



b) The Fostung property also consists of four unpatented mining claims, located in Foster Township in the Sudbury Mining Division, Ontario, Canada, comprised of 26 claim units, were recorded in the name of Fostung Resources Ltd. on June 7, 2011. Two of the four mining claim blocks consisting of two contiguous claims are located to the north east of the structural trend in the two contiguous claim blocks of 30 claims referred to in (a) above. Two of the four mining claim blocks consisting of two contiguous claims are located to the south west of the structural trend in the two contiguous claim blocks of 30 claims referred to in (a) above. Each of the four claims has an expiration date of June 7, 2013. The aggregate amount of work required to renew the four claims is CAD $10,400.

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Oil and Gas Properties (Details 1) (USD $)
3 Months Ended 12 Months Ended

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Dec. 31, 2012

Oil And Gas Properties Details 1

Asset retirement obligations, beginning of period $ 57,532 $ 55,316

Accretion expense 2,216

Liability settled upon sale of properties (57,532)

Asset retirement obligations, end of period 57,532

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Long-term asset retirement obligations, end of period $ 0 $ 57,532

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Oil and Gas Properties (Tables)
3 Months Ended

Mar. 31, 2013

Oil And Gas Properties Tables

Aggregate Amount of Capitalized Costs Relating to Crude Oil and Natural Gas Producing Activities and Aggregate Amount of Related Accumulated Depreciation Depletion and Amortization
The aggregate amount of capitalized costs relating to crude oil and natural gas producing activities and the aggregate amount of related accumulated depreciation, depletion and amortization at March 31, 2013 and December 31, 2012 were:

March 31 December 31

2013 2012 Change ($)

Unproven Properties $ - $ 537,501 $ (537,501 )

Depreciation and impairment - (513,374 ) 513,374

Oil and gas properties, net $ - $ 24,127 $ (24,127 )

Schedule of Change in Asset Retirement Obligation
The following table summarizes the activity for the Company’s asset retirement obligations:

March 31, December 31,

2013 2013

Asset retirement obligations, beginning of period $ 57,532 $ 55,316

 Accretion expense - 2,216

 Liability settled upon sale of properties (57,532 ) -

Asset retirement obligations, end of period - 57,532

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Related Party Transactions
3 Months Ended

Mar. 31, 2013

Related Party Transactions

Note 6. Related Party Transactions
On January 12, 2012, Mr. Cacace resigned from the positions of President, Chief Executive Officer, Chief Financial Officer and Director of the Company and Mr. Derek Cooper was appointed to the positions of President, Chief Executive Officer, Chief Financial Officer and Director of the Company. On June 18, 2012, Mr. Derek Cooper resigned as the Company’s President, Chief Executive Officer, Chief Financial Officer and Director. Effective as of June 19, 2012, Mr. Joseph Sierchio, one of the Company’s directors, was appointed as its Acting Interim President and Chief Executive Officer; and effective as of June 27, 2012, Ms. Janet Bien was appointed as the Company’s Chief Financial Officer.

For the three months ended March 31, 2013 and 2012, fees of $7,200 and $9,189 were paid or are due to officers of the Company. Included in accounts payable - related parties at March 31, 2013 is $4,800 (December 31, 2012 - $7,200) for management fees.

For the three month period ended March 31, 2013 and 2012, advisory board fees of $3,000 and $0 were paid to non-officer directors of the Company. Included in accounts payable – related parties at March 31, 2013 is $2,000 (December 31, 2012 - $0) for advisory fees.

For the three months ended March 31, 2013 and 2012, legal fees of $67,090 and $12,744 were paid or are due to a company controlled by our attorney, Mr. Sierchio. Included in accounts payable - related parties at March 31, 2013 is $33,862 (December 31, 2012 - $2,438) for legal fees.

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Significant Accounting Policies (Policies)
3 Months Ended

Mar. 31, 2013

Significant Accounting Policies Policies

Basis of Presentation and Principles of Accounting
The interim consolidated financial statements included herein have been prepared by the Company, without audit, in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”) pursuant to Part 210 of Regulation S-X. Certain information and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“US GAAP”) have been condensed or omitted pursuant to such SEC rules and regulations, although the Company believes that the disclosures included are adequate to make the information presented not misleading.

In management’s opinion, the unaudited consolidated financial statements contained herein reflect all adjustments, consisting solely of normal recurring items, which are necessary for the fair presentation of our financial position, results of operations, and cash flows on a basis consistent with that of our prior audited consolidated financial statements. The Company has evaluated information about subsequent events that became available to them through the date the financial statements were issued. This information relates to events, transactions or changes in circumstances that would require us to adjust the amounts reported in the financial statements or to disclose information about those events, transactions or changes in circumstances. However, the results of operations for interim periods may not be indicative of results to be expected for the full fiscal year. Therefore, these financial statements should be read in conjunction with the Company’s audited consolidated financial statements including the notes thereto for the year ended December 31, 2012, which may be found under the Company’s profile on EDGAR.

The accounting policies followed by the Company are set out in Note 2 to the audited consolidated financial statements for the year ended December 31, 2012 and have been consistently followed in the preparation of these consolidated interim financial statements.

Principles of Consolidation
These interim consolidated financial statements have been prepared in accordance with US GAAP and include the accounts of the Company and its wholly-owned subsidiaries, Fostung Resources, Limited (“Fostung”) and Entheos Energy, Inc. (“Entheos”). Collectively, they are referred to herein as “the Company.” All significant intercompany transactions and balances have been eliminated. Fostung was formed on incorporated on May 10, 2011, in Ontario Canada. Entheos was incorporated under the laws of the State of Nevada on October 5, 2000.

Applicable Accounting Guidance
Any reference in these notes to applicable accounting guidance is meant to refer to the authoritative non-governmental United States GAAP as found in the Financial Accounting Standards Board’s (“FASB”) Accounting Standards Codification (“ASC”).

Accounting Estimates
The preparation of consolidated 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 reported amounts of assets and liabilities and the reported amounts of revenues and expenses during the reporting period. Significant areas requiring the use of management estimates include the determination of impairment of mineral properties, valuation allowances for future income tax assets, fair value of non-cash stock-based compensation, common stock warrants and reclamation and environmental obligations. Actual results, as determined by future events, may differ from these estimates. Management’s judgments and estimates in these areas are based on information available from both internal and external sources, including engineers, geologists, consultants and historical experience in similar matters.

Cash and Cash Equivalents
The Company considers all highly liquid instruments purchased with an original maturity of three months or less to be cash equivalents. The Company did not have any cash equivalents at March 31, 2013 and December 31, 2012.

Mineral Properties
The Company has concluded that mineral rights meet the definition of tangible assets. Accordingly, the Company accounts for its mineral properties on a cost basis whereby all direct costs, net of pre-production revenue, relative to the acquisition of the properties are capitalized. All sales and option proceeds received are first credited against the costs of the related property, with any excess credited to earnings. Once commercial production has commenced, the net costs of the applicable property will be charged to operations using the unit-of-production method based on estimated proven and probable recoverable reserves. The net costs related to abandoned properties are charged to operations.

Costs of exploring, carrying and retaining unproven properties are charged to operations as incurred until such time that proven reserves are discovered. From that time forward, the Company will capitalize all costs to the extent that future cash flow from mineral reserves equals or exceeds the costs deferred. The deferred costs will be amortized over the recoverable reserves when a property reaches commercial production. As at March 31, 2013 and December 31, 2012, the Company did not have proven reserves. Exploration activities conducted jointly with others are reflected at the Company's proportionate interest in such activities.

Full Cost Method of Accounting for Oil and Gas Properties
The Company has elected to utilize the full cost method of accounting for its oil and gas activities. In accordance with the full cost method of accounting, all costs associated with acquisition, exploration, and development of oil and gas reserves, including directly related overhead costs and related asset retirement costs are capitalized.

All capitalized costs of oil and gas properties, including the estimated future costs to develop proved reserves, are amortized on the unit-of-production method using estimates of proved reserves once proved reserves are determined to exist. The Company did not establish proved reserves for oil and gas properties during the periods presented and as such did not record amortization.

Oil and gas properties without estimated proved reserves are assessed for impairment at each reporting date. As a result of management’s impairment analysis, the Company recorded an impairment loss of $nil and $331 during the three month periods ended March 31, 2013 and 2012, respectively.

Sales of oil and gas properties are accounted for as adjustments of capitalized costs with no gain or loss recognized, unless such adjustments would significantly alter the relationship between capitalized costs and proved reserves of oil and gas, in which case the gain or loss is recognized in income. On February 18, 2013 and February 19, 2013 the Company sold its interests in all of its oil and gas properties. During the three month period ended March 31, 2013, a gain of $49,337 was recognized in income as there are no longer any oil and gas capitalized costs.

Asset Retirement Obligation
The Company records the fair value of the liability for closure and removal costs associated with the legal obligations upon retirement or removal of any tangible long-lived assets by recording the fair value of the liability during the period in which it was incurred. The associated asset retirement costs are capitalized as part of the carrying amount of the long-lived asset. The increase in carrying value of a property associated with the capitalization of an asset retirement obligation is included in oil and gas properties in the balance sheets. The Company’s asset retirement obligation consists of costs related to the plugging of wells, removal of facilities and equipment and site restoration on its oil and gas properties. The asset retirement liability is allocated to operating expense using a systematic and rational method. Asset retirement obligations amounted to $nil and $57,532 at March 31, 2013 and December 31, 2012, respectively. See “Note 3. Oil and Gas Properties” for further discussion.

Impairment of Long-Lived Assets
The Company reviews and evaluates its long-lived assets for impairment at each balance sheet date and documents such impairment testing. The tests include an evaluation of the assets and events or changes in circumstances that would indicate that the related carrying amounts may not be recoverable.

Oil and gas properties are subject to a “ceiling test” which basically limits capitalized costs to the sum of the estimated future net revenues from proved reserves, discounted at 10% per annum to present value, based on current economic and operating conditions, adjusted for related income tax effects.

Mineral properties in the exploration stage are monitored for impairment based on factors such as the Company’s continued right to explore the area, exploration reports, assays, technical reports, drill results and the Company’s continued plans to fund exploration programs on the property, whether sufficient work has been performed to indicate that the carrying amount of the mineral property cost carried forward as an asset will not be fully recovered, even though a viable mine has been discovered.

The tests for long-lived assets in the exploration, development or producing stage that would have a value beyond proven and probable reserves would be monitored for impairment based on factors such as current market value of the mineral property and results of exploration, future asset utilization, business climate, mineral prices and future undiscounted cash flows expected to result from the use of the related assets. Recoverability of assets to be held and used is measured by a comparison of the carrying amount of an asset to the estimated future net undiscounted cash flows expected to be generated by the asset, including evaluating its reserves beyond proven and probable amounts.

The Company’s policy is to record an impairment loss in the period when it is determined that the carrying amount of the asset may not be recoverable either due to impairment or by abandonment of the property. The impairment loss is calculated as the amount by which the carrying amount of the asset exceeds its fair value. While the Company incurred losses from operations, these losses have not been in excess of planned expenditures on the specific mineral properties in order to ultimately realize their value.

Oil and Gas Revenue Recognition
The Company recognizes oil and gas revenues when oil and gas production is sold to a purchaser at a fixed or determinable price, when delivery has occurred and title has transferred, and if collectability of the revenue is probable. Delivery occurs and title is transferred when production has been delivered to a purchaser’s pipeline or truck. As a result of the numerous requirements necessary to gather information from purchasers or various measurement locations, calculate volumes produced, perform field and wellhead allocations, distribute and disburse funds to various working interest partners and royalty owners, the collection of revenues from oil and gas production may take up to 45 days following the month of production. Therefore, the Company may make accruals for revenues and accounts receivable based on estimates of its share of production. Since the settlement process may take 30 to 60 days following the month of actual production, its financial results may include estimates of production and revenues for the related time period. The Company will record any differences between the actual amounts ultimately received and the original estimates in the period they become finalized.

Income Taxes
The Company recognizes income taxes on an accrual basis based on tax position taken or expected to be taken in our tax returns. A tax position is defined as a position in a previously filed tax return or a position expected to be taken in a future tax filing that is reflected in measuring current or deferred income tax assets and liabilities. Tax positions are recognized only when it is more likely than not (i.e., likelihood of greater than 50%), based on technical merits, that the position would be sustained upon examination by taxing authorities. Tax positions that meet the more likely than not threshold are measured using a probability-weighted approach as the largest amount of tax benefit that is greater than 50% likely of being realized upon settlement. Income taxes are accounted for using an asset and liability approach that requires the recognition of deferred tax assets and liabilities for the expected future tax consequences of events that have been recognized in our financial statements or tax returns. A valuation allowance is established to reduce deferred tax assets if all, or some portion, of such assets will more than likely not be realized. Should they occur, our policy is to classify interest and penalties related to tax positions as interest expense. Since our inception, no such interest or penalties have been incurred.

Earnings (Loss) Per Share
The Company presents both basic and diluted earnings per share (“EPS”) amounts. Basic EPS is calculated by dividing net income by the weighted average number of common shares outstanding during the period presented. Diluted EPS amounts are based upon the weighted average number of common and common equivalent shares outstanding during the period presented. There were no dilutive shares outstanding for the three month period ended March 31, 2013 and 2012.

Foreign Currency Translation
Transactions and account balances originally stated in currencies other than the U.S dollar have been translated into U.S. dollars as follows:

· Revenue and expense items are translated at the average exchange rate for the period in which they are incurred.

· Non-monetary assets and liabilities at the rate of exchange in effect on the dates the assets were acquired or the liabilities were incurred.

· Monetary assets and liabilities at the exchange rate at the balance sheet date.

Exchange gains and losses are recorded in operations in the period in which they occur, except for exchange gains and losses related to translation of monetary assets and liabilities associated with mineral properties, which are deferred and included in mineral properties.

Comprehensive income
Comprehensive loss is comprised of net loss and foreign currency translation adjustments for the periods presented.

Related Party Transactions
A related party is generally defined as (i) any person who holds 10% or more of the Company’s securities and their immediate families, (ii) the Company’s management, (iii) someone who directly or indirectly controls, is controlled by or is under common control with the Company, or (iv) anyone who can significantly influence the financial and operating decisions of the Company. A transaction is considered to be a related party transaction when there is a transfer of resources or obligations between related parties. See “Note 6. Related Party Transactions” for further discussion.

Concentration of Risk
Financial instruments that subject the Company to concentrations of credit risk consist primarily of cash and cash equivalents, and accounts receivable. The Company occasionally has cash deposits in excess of federally insured limits. The Company has not experienced any losses related to these balances, and management believes its credit risk to be minimal. Accounts receivable are with the operators of the oil wells in which the Company participates. Given the close working relationship between the operators and the Company, management believes its credit risk is minimal.

Fair Values of Financial Instruments
The Company measures certain financial assets and liabilities at fair value based on the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in on orderly transaction between market participants. The carrying amounts of cash and cash equivalents, accounts receivable, and accounts payable approximate fair value due to the short-term nature of maturity of the instruments.

Recently Issued Accounting Standards Updates
Accounting Standards Update 2012-02: Intangibles - Goodwill and Other (Topic 350): Testing Indefinite-Lived Intangible Assets for Impairment

In July 2012, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2012-02, “Intangibles - Goodwill and Other (Topic 350): Testing Indefinite-Lived Intangible Assets for Impairment,” allowing entities to make a qualitative evaluation about the likelihood of impairment of an indefinite-lived intangible asset to determine whether the quantitative test is required, as opposed to required annual quantitative impairment testing. The update is effective for interim and annual impairment tests performed for fiscal years beginning after September 15, 2012. The adoption of this guidance did not affect the Company's financial condition, results of operations, or cash flows.

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Oil and Gas Properties
3 Months Ended

Mar. 31, 2013

Oil And Gas Properties

Note 3. Oil and Gas Properties
On February 18, 2013, we completed the sale of our working interest in the Onnie Ray #1, Haile #1, Pearce #1 and Stahl #1 oil wells. We entered into an Assignment Agreement with Leexus Oil LLC, the wells operator, whereby the Company assigned its right, title and interest in the oil, gas and mineral leases and the oil and gas wells. Consideration for the assignment was the assumption of all outstanding liabilities and assumption of all future payments for any and all work performed on the wells.

On February 19, 2013, we completed the sale of our working interest in the Cooke #6 well. We entered into an Assignment Agreement with Millennium Petro-Physics, the well operator, whereby we assigned the right, title and interest in the oil, gas and mineral leases and the oil and gas wells. Consideration for the assignment was $3,000 cash.

The carrying amount of the oil and gas properties was $24,127 on the date of disposal. The related asset retirement obligation amounted to $57,532 and liabilities assumed amounted to $12,932. Including the $3,000 cash received, the Company recognized a gain of $49,337 during the three months ended March 31, 2013 as a result of the disposal.

The aggregate amount of capitalized costs relating to crude oil and natural gas producing activities and the aggregate amount of related accumulated depreciation, depletion and amortization at March 31, 2013 and December 31, 2012 were:

March 31 December 31

2013 2012 Change ($)

Unproven Properties $ - $ 537,501 $ (537,501 )

Depreciation and impairment - (513,374 ) 513,374

Oil and gas properties, net $ - $ 24,127 $ (24,127 )

There were no material costs incurred in oil and gas property acquisition, exploration and development activities for the three month periods ended March 31, 2013 and 2012

Due to the 40 to 60 day lead-time for receiving financial results of well operating activities, the effective date of the sale to Leexus Oil LLC and Millennium Petro-Physics was January 1, 2013. Accordingly, we had no revenue, operating expenses or impairment charges for the three month period ended March 31, 2013.

Asset Retirement Obligation

The following table summarizes the activity for the Company’s asset retirement obligations:

March 31, December 31,

2013 2013

Asset retirement obligations, beginning of period $ 57,532 $ 55,316

 Accretion expense - 2,216

 Liability settled upon sale of properties (57,532 ) -

Asset retirement obligations, end of period - 57,532

Less: current portion - -

Long-term asset retirement obligations, end of period $ - $ 57,532

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Oil and Gas Properties (Details Narrative) (USD $)
3 Months Ended

Mar. 31, 2013

Mar. 31, 2012

Oil And Gas Properties Details Narrative

Disposal of oil and gas properties $ 49,337

Cash received $ 3,000

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CONSOLIDATED BALANCE SHEETS (USD $)	Mar. 31, 2013	Dec. 31, 2012
Current assets
Cash and cash equivalents	$ 490,050	$ 513,595
Accounts receivable		800
Prepaid expenses		7,562
Total current assets	490,050	521,957
Oil and gas properties
Unproven properties		537,501
Accumulated depreciation, depletion, amortization and impairment		(513,374)
Oil and gas properties, net		24,127
Mineral properties	519,750	519,750
Total assets	1,009,800	1,065,834
Current liabilities
Accounts payable and accrued liabilities	22,415	30,905
Accounts payable - related parties	40,661	9,638
Total current liabilities	63,076	40,543
Asset retirement obligation	0	57,532
Total liabilities	63,076	98,075
STOCKHOLDERS' EQUITY
Preferred stock: $0.0001 par value: Authorized: 10,000,000 shares, Issued and outstanding: nil
Common stock: $0.00001 par value: Authorized: 200,000,000 shares, Issued and outstanding: 63,075,122 shares (2012: 63,075,122)	631	631
Additional paid-in capital	5,462,236	5,462,236
Accumulated deficit	(4,512,039)	(4,491,004)
Accumulated other comprehensive loss	(4,104)	(4,104)
Total stockholders' equity	946,724	967,759
Total liabilities and stockholders' equity	$ 1,009,800	$ 1,065,834

CONSOLIDATED STATEMENT STOCKHOLDER’S EQUITY (unaudited) (USD $)	Common Stock [Member]	Additional Paid In Capital [Member]	Accumulated (deficit)	Accumulated other comprehensive (loss)	Total
Beginning Balance, Amount at Dec. 31, 2011	$ 631	$ 5,462,236	$ (4,247,045)	$ (4,104)	$ 1,211,718
Beginning Balance, Shares at Dec. 31, 2011	63,075,122
Net loss			(243,959)		(243,959)
Ending Balance, Amount at Dec. 31, 2012	631	5,462,236	(4,491,004)	(4,104)	967,759
Ending Balance, Shares at Dec. 31, 2012	63,075,122
Net loss			(21,035)		(21,035)
Ending Balance, Amount at Mar. 31, 2013	$ 631	$ 5,462,236	$ (4,512,039)	$ (4,104)	$ 946,724
Ending Balance, Shares at Mar. 31, 2013	63,075,122

CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited) (USD $)	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Cash flows from operating activities
Net loss	$ (21,035)	$ (83,253)
Impairment and depreciation		331
Accretion of asset retirement obligation		729
Gain on disposal of oil and gas properties	(49,337)
Changes in operating assets and liabilities:
Decrease (increase) in receivables	800	6,752
Decrease (increase) in prepaid expenses	7,562	(10,200)
(Decrease) increase in accounts payable and accrued liabilities including related party payables	35,465	(40,056)
Net cash flows from operating activities	(26,545)	(125,697)
Cash flows from investing activities
Proceeds from disposal of oil and gas properties	3,000
Net cash flows from investing activities	3,000
Effect of exchange rate changes on cash and cash equivalents		(769)
Decrease in cash and cash equivalents	(23,545)	(126,466)
Cash and cash equivalents, beginning of period	513,595	787,771
Cash and cash equivalents, end of period	490,050	661,305
Supplemental disclosure of cash flow information:
Interest paid in cash
Income tax paid in cash

CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	Mar. 31, 2013	Dec. 31, 2012
STOCKHOLDERS' EQUITY
Preferred stock, par value	$ 0.0001	$ 0.0001
Preferred stock, Authorized	10,000,000	10,000,000
Preferred stock, shares Issued	0	0
Preferred stock, shares outstanding	0	0
Common stock, par value	$ 0.00001	$ 0.00001
Common stock, Authorized	200,000,000	200,000,000
Common stock, shares Issued	63,075,122	63,075,122
Common stock, shares outstanding	63,075,122	63,075,122

Significant Accounting Policies (Details Narrative) (USD $)	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Dec. 31, 2012
Significant Accounting Policies Details Narrative
Oil and gas properties, impairment Loss	$ 0	$ 331
Sold interests in oil and gas properties	49,337
Asset retirement obligation	$ 0		$ 57,532

Document and Entity Information	3 Months Ended
Document and Entity Information	Mar. 31, 2013	May 15, 2013
Document And Entity Information
Entity Registrant Name	Janus Resources, Inc.
Entity Central Index Key	0001016708
Document Type	10-Q
Document Period End Date	Mar. 31, 2013
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Is Entity a Well-known Seasoned Issuer?	No
Is Entity a Voluntary Filer?	No
Is Entity's Reporting Status Current?	Yes
Entity Filer Category	Smaller Reporting Company
Entity Common Stock, Shares Outstanding		63,075,122
Document Fiscal Period Focus	Q1
Document Fiscal Year Focus	2013

Oil and Gas Properties (Details) (USD $)	3 Months Ended
Oil and Gas Properties (Details) (USD $)	Mar. 31, 2013	Dec. 31, 2012
Oil And Gas Properties Details
Unproven properties		$ 537,501
Depreciation and impairment		(513,374)
Oil and gas properties, net		24,127
Unproven properties, change	(537,501)
Depreciation and impairment, change	513,374
Oil and gas properties, net, change	$ (24,127)

CONSOLIDATED STATEMENTS OF OPERATIONS (unaudited) (USD $)	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Revenue
Oil and gas sales		$ 6,053
Expenses
Lease operating expenses		5,025
Exploration costs		3,138
General and administrative expenses	70,372	80,812
Impairment and depreciation		331
Total operating expenses	70,372	89,306
Operating Loss	(70,372)	(83,253)
Other income
Gain on disposal of oil and gas properties	49,337
Total other income	49,337
Net loss	$ (21,035)	$ (83,253)
Earnings per share - basic and diluted
Loss per common share	$ 0.00	$ 0.00
Weighted average shares outstanding	63,075,122	63,075,122

Oil and Gas Properties (Details 1) (USD $)	3 Months Ended	12 Months Ended
Oil and Gas Properties (Details 1) (USD $)	Mar. 31, 2013	Dec. 31, 2012
Oil And Gas Properties Details 1
Asset retirement obligations, beginning of period	$ 57,532	$ 55,316
Accretion expense		2,216
Liability settled upon sale of properties	(57,532)
Asset retirement obligations, end of period		57,532
Less: current portion
Long-term asset retirement obligations, end of period	$ 0	$ 57,532

Organization Nature and Continuance of Operations (Details Narrative) (USD $)	Mar. 31, 2013	Dec. 31, 2012
Organization Nature And Continuance Of Operations Details Narrative
Accumulated deficit	$ 4,512,039	$ 4,491,004

Related Party Transactions (Details Narrative) (USD $)					3 Months Ended						3 Months Ended
Related Party Transactions (Details Narrative) (USD $)	Mar. 31, 2013	Dec. 31, 2012	Mar. 31, 2013 Management Fee [Member]	Dec. 31, 2012 Management Fee [Member]	Mar. 31, 2013 Management Fee [Member] Officer [Member]	Mar. 31, 2012 Management Fee [Member] Officer [Member]	Mar. 31, 2013 Management Fee [Member] Non Officer Director [Member]	Mar. 31, 2012 Management Fee [Member] Non Officer Director [Member]	Mar. 31, 2013 Legal Fee [Member]	Dec. 31, 2012 Legal Fee [Member]	Mar. 31, 2013 Legal Fee [Member] Company's attorney, Mr. Sierchio [Member]	Mar. 31, 2012 Legal Fee [Member] Company's attorney, Mr. Sierchio [Member]	Mar. 31, 2013 Advisory Fees	Dec. 31, 2012 Advisory Fees
Fees paid or due to related party					$ 7,200	$ 9,189	$ 3,000	$ 0			$ 67,090	$ 12,744
Accounts payable - related parties	$ 40,661	$ 9,638	$ 4,800	$ 7,200					$ 33,862	$ 2,438			$ 2,000	$ 0

CONSOLIDATED STATEMENT COMPREHENSIVE LOSS (unaudited) (USD $)	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Consolidated Statement Comprehensive Loss
Net loss	$ (21,035)	$ (83,253)
Other comprehensive loss
Foreign currency translation adjustments		(769)
Total comprehensive loss	$ (21,035)	$ (84,022)

Oil and Gas Properties (Details Narrative) (USD $)	3 Months Ended
Oil and Gas Properties (Details Narrative) (USD $)	Mar. 31, 2013	Mar. 31, 2012
Oil And Gas Properties Details Narrative
Disposal of oil and gas properties	$ 49,337
Cash received	$ 3,000