Annual and Transition Report (foreign Private Issuer) (20-f)

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 20-F

o	REGISTRATION STATEMENT PURSUANT TO SECTION 12(b) OR (g) OF THE SECURITIES EXCHANGE ACT OF 1934
OR
x	ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

	For the fiscal year ended December 31, 2014

OR
o	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the transition period from ____________ to __________

OR
o	SHELL COMPANY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	Date of event requiring this shell company report: ______

Commission file number: 000-500934

STRATA OIL & GAS INC.

(Exact name of Registrant as specified in its charter)

Alberta, Canada

(Jurisdiction of incorporation or organization)

10010 - 98 Street
PO Box 7770
Peace River, AB
T8S 1T3

(Address of principal executive offices)

877-237-5443

Securities registered pursuant to Section 12(b) of the Act:

None

Securities registered pursuant to Section 12(g) of the Act:

Common Stock

(Title of Class)

Securities for which there is a reporting obligation pursuant to Section 15(d) of the Act: None

Indicate the number of outstanding shares of each of the issuer's classes of capital or common stock as of the close of the period covered by the Annual Report: The registrant has one class of Common Stock with 89,383,183 shares outstanding at December 31, 2014 and 91,194,183 shares outstanding at April 2, 2015. No preferred shares are issued and outstanding.

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes o No x

If this report is an annual or transition report, indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934. Yes o No o

Note – Checking the box above will not relieve any registrant required to file reports pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 from their obligations under those Sections.

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 ninety days. Yes x No o

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

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

Large accelerated filer o

Accelerated filer o

Non-accelerated filer x

Indicate by check mark which basis of accounting the registrant has used to prepare the financial statements included in this filing:

U.S. GAAP x

International Financial Reporting Standards as issued by the International Accounting Standards Board o

Other o

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

STRATA OIL & GAS INC.

FORM 20-F ANNUAL REPORT 2014

TABLE OF CONTENTS

Oil and Gas Glossary
Introduction

Part I

Item 1.	Identity of Directors, Senior Management and Advisers	5
Item 2.	Offer Statistics and Expected Timetable	5
Item 3.	Key Information	5
Item 4.	Information on the Company	12
Item 4A.	Unresolved Staff Comments	27
Item 5.	Operating and Financial Review and Prospects	27
Item 6.	Directors, Senior Management and Employees	34
Item 7.	Major Shareholders and Related Party Transactions	36
Item 8.	Financial Information	37
Item 9.	The Offer and Listing	37
Item 10.	Additional Information	38
Item 11.	Quantitative and Qualitative Disclosures About Market Risk	43
Item 12.	Description of Securities Other Than Equity Securities	43

Part II

Item 13.	Defaults, Dividend Arrearages and Delinquencies	44
Item 14.	Material Modifications to the Rights of Security Holders and Use of Proceeds	44
Item 15.	Controls and Procedures	44
Item 16.	Reserved
Item 16A.	Audit Committee Financial Expert	45
Item 16B.	Code of Ethics	45
Item 16C.	Principal Accountant Fees and Services	46
Item 16D.	Exemptions from the Listing Standards for Audit Committees	46
Item 16E.	Purchases of Equity Securities by the Issuer and Affiliated Purchasers	46
Item 16F.	Change in Registrants Certifying Accountant	46
Item 16G.	Corporate Governance	46

Part III

Item 17.	Financial Statements	47
Item 18.	Financial Statements	47
Item 19.	Exhibits	47

Signature Page		48

Certifications

OIL AND GAS GLOSSARY

Term	Definition

Basin	A depressed area where sediments have accumulated during geologic time and considered to be prospective for oil and gas deposits
Bitumen	Heavy, viscous crude oil
Bluesky Formation	The Bluesky is fine to medium grained, usually glauconitic, partly calcareous or sideritic, salt and pepper sandstone with fair porosity. Chert granules and pebbles occur near the top, with thin shale interbedded throughout. The thickness is 0-46 meters in the Peace River plains subsurface. It thins to the south and southeast
CHOPS	Cold Heavy Oil Production with Sand
Carboniferous	The period of geological time between 360 and 286 million years ago. A series of stratified rocks and associated volcanic rocks which occur above the Devonian or Old Sandstone and below the Permian or Triassic systems belonging to the Carboniferous period
Cretaceous Period	A period 144 to 65 million years ago
Debolt Formation	Lies above the Elkton Formation and ranges from mid-to-upper Visean in age (345.3 to 326.4 million years ago)
Development	The phase in which a proven oil or gas field is brought into production by drilling production (development) wells
Drilling	The using of a rig and crew for the drilling, suspension, production testing, capping, plugging and abandoning, deepening, plugging back, sidetracking, re-drilling or reconditioning of a well
Drilling Logs	Recorded observations made of rock chips cut from the formation by the drill bit, and brought to the surface with the mud, as well as rate of penetration of the drill bit through rock formations. Used by geologists to obtain formation data
Exploration	The phase of operations which covers the search for oil or gas by carrying out detailed geological and geophysical surveys followed up where appropriate by exploratory drilling. Compare to "Development" phase
Jurassic Period	Between 206 and 144 million years ago
Mineral Lease	A legal instrument executed by a mineral owner granting exclusive right to another to explore, drill and produce oil and gas from a piece of land
Porosity	The ratio of the volume of void spaces in a rock or sediment to the total volume of the rock or sediment
Reserves	Generally the amount of oil or gas in a particular reservoir that is available for production
Reservoir	The underground rock formation where oil and gas has accumulated. It consists of a porous rock to hold the oil or gas, and a cap rock that prevents its escape

FORWARD-LOOKING STATEMENTS

This Annual Report on Form 20-F contains forward-looking information. Forward-looking information includes statements relating to future actions, prospective products, future performance or results of current or anticipated products, sales and marketing efforts, costs and expenses, interest rates, outcome of contingencies, financial condition, results of operations, liquidity, business strategies, cost savings, objectives of management of Strata Oil & Gas Inc. (hereinafter referred to as the “Company,” “Strata” or “we”) and other matters. Forward-looking information may be included in this Annual Report on Form 20-F or may be incorporated by reference from other documents filed with the Securities and Exchange Commission (the “SEC”) by the Company. One can find many of these statements by looking for words including, for example, “believes,” “expects,” “anticipates,” “estimates” or similar expressions in this Annual Report on Form 20-F or in documents incorporated by reference in this Annual Report on Form 20-F. The Company undertakes no obligation to publicly update or revise any forward-looking statements, whether as a result of new information or future events, except as required by applicable law.

The Company has based the forward-looking statements relating to the Company’s operations on management’s current expectations, estimates and projections about the Company and the industry in which it operates. These statements are not guarantees of future performance and involve risks, uncertainties and assumptions that we cannot predict. In particular, we have based many of these forward-looking statements on assumptions about future events that may prove to be inaccurate. Accordingly, the Company’s actual results may differ materially from those contemplated by these forward-looking statements. Any differences could result from a variety of factors, including, but not limited to general economic and business conditions, competition, and other factors, including those described in Item 3.D. “Risk Factors.”

PART I

Item 1. Identity of Directors, Senior Management and Advisers

Not applicable.

Item 2. Offer Statistics and Expected Timetable

Not applicable.

Item 3. Key Information

A. Selected Financial Data

The following sets forth selected financial information of Strata prepared in accordance with accounting principles generally accepted in the United States for the fiscal years ended December 31, 2014, 2013, 2012, 2011 and 2010.

The selected financial information and operating information may not be indicative of Strata’s future performance and should be read in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations.” The selected financial data set forth below has been extracted from, and is qualified by reference, to the audited financial statements included herein at Item 18.

SELECTED OPERATIONS DATA

(in U.S. dollars)

	Strata Oil & Gas Inc.
	Years Ended December 31,
	2014			2013			2012			2011		2010
Revenue	$	–		$	–		$	–		$	–	$	–
Expenses		753,287			574,609			241,995			177,252		972,357
Other income (expense), net		470,186			(2,223,559	)		(1,614,795	)		1,806,507		4,474,395
Net income (loss)	$	(283,101	)		(2,798,169	)	$	(1,856,790	)	$	1,629,255	$	3,502,038

Basic and diluted income (loss) per share:
From continuing operations	$	(0.00	)		(0.04	)	$	(0.03	)	$	0.02	$	0.05
Basic weighted average number of common shares outstanding (in millions)		87.2			80.1			71.3			68.8		66.4
Diluted weighted average number of common shares outstanding (in millions)		N/A			N/A			N/A			69.2		73.2

BALANCE SHEET DATA

(in U.S. Dollars)

	Strata Oil & Gas Inc.
	December 31,
	2014			2013			2012			2011			2010

Cash and cash equivalents	$	118,873		$	440,612		$	134,125		$	217,504		$	151,283
Other current assets		176,806			72,199			5,222			23,827			51,157
Deposits		133,745			121,870			123,634			116,172			114,139
Property and equipment, net		–			–			–			1,361			2,244
Oil and gas property interests		7,423,966			7,784,848			8,195,885			7,901,703			7,967,915
Total assets		7,853,390			8,419,529			8,458,866			8,260,567			8,286,738
Current liabilities		4,564,235			5,180,432			2,377,418			541,947			2,097,438
Asset retirement obligations		138,049			139,623			138,129			127,688			119,041
Additional paid-in capital		21,905,643			21,304,071			21,069,422			21,028,596			21,025,596
(Accumulated deficit) retained earnings		(18,946,856	)		(18,663,755	)		(15,865,586	)		(14,008,796	)		(15,638,051	)
Accumulated other comprehensive income		192,319			459,158			739,483			571,132			682,714
Total liabilities and stockholders’ equity		7,853,390			8,419,529			8,458,866			8,260,567			8,286,738

Dividends

We have never paid or declared dividends on our shares of common stock.

Exchange Rates

In this Annual Report, unless otherwise specified, all dollar amounts are expressed in United States Dollars (USD$). The Government of Canada permits a floating exchange rate to determine the value of the Canadian Dollar against the U.S. Dollar (US$), therefore, this Annual Report may contain conversions of certain amounts in United States dollars into the Company’s functional currency, Canadian dollars, based upon the exchange rate in effect at the end of the month or of the fiscal year to which the amount relates, or the exchange rate on the date specified. For such purposes, the exchange rate means the daily noon historical exchange rate as reported online by the Bank of Canada at http://www.bankofcanada.ca/rates/exchange/10-year-lookup and reference “U.S dollar (noon)”. These translations should not be construed as representations that the Canadian dollar amounts actually represent such United States dollar amounts or that Canadian dollars could be converted into United States dollars at the rate indicated or at any other rate.

The following table sets forth the exchange rates for the Canadian Dollar at the end of each of the five fiscal years ended December 31, 2014, 2013, 2012, 2011 and 2010, and the average rates for the period and the range of high and low rates for the period. The data for March 2015 and for each month during the most recent six months is also provided.

Exchange Rates for Canadian Versus U.S. Dollars

The exchange rate as of December 31, 2014 was CDN $1.16 per U.S. $1.00.

The exchange rate as of April 2, 2015 was CDN $1.26 per U.S. $1.00.

Exchange Rates for Canadian Versus U.S. Dollars

(High/low rates for latest six months)

	High	Low
March, 2015	1.28	1.24
February, 2015	1.27	1.24
January, 2015	1.27	1.17
December, 2014	1.16	1.13
November, 2014	1.14	1.12
October 2014	1.13	1.11

Exchange Rates for Canadian Versus U.S. Dollars

		Average ($)
For the twelve months ended December 31, 2014		1.10
For the twelve months ended December 31, 2013		1.03
For the twelve months ended December 31, 2012		1.00
For the twelve months ended December 31, 2011		0.99
For the twelve months ended December 31, 2010		1.00

B. Capitalization and Indebtedness

Not applicable.

C. Reasons for the offer and use of proceeds

Not applicable.

D. Risk Factors

An investment in the Company has a high degree of risk. Before you invest you should carefully consider the risks and uncertainties described below and the other information in this Annual Report. If any of the following risks actually occur, our business, operating results and financial condition could be harmed and the value of our stock could go down. This means you could lose all or a part of your investment.

RISKS RELATING TO OUR COMPANY

1. We are an exploration stage company, with limited operating history, which raises substantial doubt as to our ability to successfully develop profitable business operations and makes an investment in our common shares very risky.

We have only recently commenced oil and gas exploration operations. Our prospects must be considered in light of the risks, expenses and difficulties frequently encountered in establishing a business in the oil and natural gas industries. We have yet to generate any revenues from operations. There is nothing at this time in which to base an assumption that our business operations will prove to be successful or that we will ever be able to operate profitably. Our future operating results will depend on many factors, including:

	·	our ability to raise adequate working capital;
	·	success of our exploration and development;
	·	demand for natural gas and oil;
	·	the level of our competition;
	·	our ability to attract and maintain key management and employees; and
	·	our ability to efficiently explore, develop and produce sufficient quantities of marketable natural gas or oil in a highly competitive and speculative environment while maintaining quality and controlling costs.

To achieve profitable operations, we must, alone or with others, successfully execute on the factors stated above. If we are not successful in executing any of the above stated factors, our business will not be profitable and may never even generate any revenue, which make our common shares a less attractive investment and may harm the trading of our common shares.

2. At this stage of our business, even with our good faith efforts, potential investors have a high probability of losing their investment.

Because the nature of our business is expected to change as a result of shifts in the market price of oil and natural gas, competition, and the development of new and improved technology, management forecasts are not necessarily indicative of future operations and should not be relied upon as an indication of future performance.

Our management may incorrectly estimate projected occurrences and events within the timetable of its business plan, which would have an adverse effect on our results of operations and, consequently, make our common shares a less attractive investment and harm the trading of our common shares. Investors may find it difficult to sell their shares.

3. If capital is not available to fund future operations, we will not be able to pursue our business plan and operations would come to a halt and our common shares would be nearly worthless.

Cash on hand is not sufficient to fund our anticipated operating needs for the next twelve months. We will require substantial additional capital to participate in the development of our properties which have not had any production of oil or natural gas as well as for acquisition and/or development of other producing properties. Because we currently do not have any cash flow from operations, we need to raise additional capital which may be in the form of loans from current shareholders and/or from private equity offerings. Our ability to access capital will depend on our success in participating in properties that are successful in exploring for and producing oil and gas at profitable prices. It will also be dependent upon the status of the capital markets at the time such capital is sought. Should sufficient capital not be available, the development of our business plan could be delayed and, accordingly, the implementation of our business strategy would be adversely affected. In such event it would not be likely that investors would obtain a profitable return on their investments or a return of their investments at all.

4. We are heavily dependent on Ron Daems, our CEO and President. The loss of Mr. Daems, whose knowledge, leadership and technical expertise upon which we rely, would harm our ability to execute our business plan.

Our success depends heavily upon the continued contributions of Ron Daems, whose knowledge, leadership and technical expertise would be difficult to replace. Our success is also dependent on our ability to retain and attract experienced engineers, geoscientists and other technical and professional staff. We do not maintain any key person insurance on Mr. Daems or any of our officers and directors. If we were to lose his services, our ability to execute our business plan would be harmed and we may be forced to cease operations until such time, if ever, we could hire a suitable replacement for Mr. Daems.

5. Volatility of oil and gas prices and markets could make it more difficult for us to achieve profitability and less likely for investors in our common shares to receive a return on their investment.

Our ability to achieve profitability is substantially dependent on prevailing prices for natural gas and oil. The amounts and price obtainable for any oil and gas production that we achieve will be affected by market factors beyond our control. If these factors are not favorable over time to our financial interests, it is likely that owners of our common shares will lose their investments. Such factors include:

	·	worldwide or regional demand for energy, which is affected by economic conditions
	·	the domestic and foreign supply of natural gas and oil
	·	weather conditions
	·	domestic and foreign governmental regulations
	·	political conditions in natural gas and oil producing regions
	·	the ability of members of the Organization of Petroleum Exporting Countries to agree upon and maintain oil prices and production levels
	·	the price and availability of other fuels

6. Drilling wells is speculative and often involves significant costs that may be more than our estimates. Any material inaccuracies in drilling costs, estimates or underlying assumptions will reduce the profitability of our business and will negatively affect our results of operations.

Developing and exploring for natural gas and oil involves a high degree of operational and financial risk, which precludes definitive statements as to the time required and costs involved in reaching certain objectives. The budgeted costs of drilling, completing and operating wells are often exceeded and can increase significantly when drilling costs rise due to a tightening in the supply of various types of oilfield equipment and related services. Drilling may be unsuccessful for many reasons, including title problems, weather, cost overruns, equipment shortages and mechanical difficulties. Moreover, the successful drilling of a natural gas or oil well does not ensure a profit on investment. Exploratory wells bear a much greater risk of loss than development wells. A variety of factors, both geological and market-related, can cause a well to become uneconomical or only marginally economic such as:

	·	fires
	·	explosions
	·	blow-outs and surface cratering
	·	uncontrollable flows of oil, natural gas, and formation water
	·	natural disasters, such as hurricanes and other adverse weather conditions
	·	pipe, cement, or pipeline failures
	·	casing collapses
	·	embedded oil field drilling and service tools
	·	abnormally pressured formations
	·	environmental hazards, such as natural gas leaks, oil spills, pipeline ruptures and discharges of toxic gases

If we experience any of these problems, it could affect well bores, gathering systems and processing facilities, which could adversely affect our ability to conduct operations. We could also incur substantial losses as a result of:

	·	injury or loss of life
	·	severe damage to and destruction of property, natural resources and equipment
	·	pollution and other environmental damage
	·	clean-up responsibilities
	·	regulatory investigation and penalties
	·	suspension of our operations
	·	repairs to resume operations

7. The unavailability or high cost of drilling rigs, equipment, supplies, personnel and other services could adversely affect our ability to execute on a timely basis our development, exploitation and exploration plans within our budget.

Shortages or an increase in cost of drilling rigs, equipment, supplies or personnel could delay or interrupt our operations, which could impact our financial condition and results of operations. Drilling activity in the geographic areas in which we conduct drilling activities may increase, which would lead to increases in associated costs, including those related to drilling rigs, equipment, supplies and personnel and the services and products of other vendors to the industry. Increased drilling activity in these areas may also decrease the availability of rigs. We do not have any contracts with providers of drilling rigs and, consequently we may not be able to obtain drilling rigs when we need them. Therefore, our drilling and other costs may increase further and necessary equipment and services may not be available to us at economical prices.

8. We are subject to complex laws and regulations, including environmental regulations, which can adversely affect the cost, manner or feasibility of doing business.

Development, production and sale of natural gas and oil in Canada are subject to extensive laws and regulations, including environmental laws and regulations. We may be required to make large expenditures to comply with environmental and other governmental regulations. Matters subject to regulation include:

	·	location and density of wells
	·	the handling of drilling fluids and obtaining discharge permits for drilling operations
	·	accounting for and payment of royalties on production from state, federal and Indian lands
	·	bonds for ownership, development and production of natural gas and oil properties
	·	transportation of natural gas and oil by pipelines
	·	operation of wells and reports concerning operations
	·	taxation

Under these laws and regulations, we could be liable for personal injuries, property damage, oil spills, discharge of hazardous materials, remediation and clean-up costs and other environmental damages. Failure to comply with these laws and regulations may also result in the suspension or termination of our operations and subject us to administrative, civil and criminal penalties. Moreover, these laws and regulations could change in ways that substantially increase our costs. Accordingly, any of these liabilities, penalties, suspensions, terminations or regulatory changes could result in a material adverse affect on our financial condition and results of operations which could potentially force us to cease our business operations.

9. Our oil and gas operations may expose us to environmental liabilities.

If we experience any leakage of crude oil and/or gas from the subsurface portions of a well, our gathering system could cause degradation of fresh groundwater resources, as well as surface damage, potentially resulting in suspension of operation of a well, fines and penalties from governmental agencies, expenditures for remediation of the affected resource and liabilities to third parties for property damages and personal injuries. In addition, any sale of residual crude oil collected as part of the drilling and recovery process could impose liability on us if the entity to which the oil was transferred fails to manage the material in accordance with applicable environmental health and safety laws.

10. Exploratory drilling involves many risks and we may become liable for pollution or other liabilities which may have an adverse effect on our financial position.

Drilling operations generally involve a high degree of risk. Hazards such as unusual or unexpected geological formations, power outages, labor disruptions, blow-outs, sour gas leakage, fire, inability to obtain suitable or adequate machinery, equipment or labor and other risks are involved. We may become subject to liability for pollution or hazards against which we cannot adequately insure or may elect not to insure. Incurring any such liability may have a material adverse effect on our financial position and operations.

11. The potential profitability of oil and gas ventures depends upon factors beyond our control.

The potential profitability of oil and gas properties is dependent upon many factors beyond our control. For instance, world prices and markets for oil and gas are unpredictable, highly volatile, potentially subject to governmental fixing, pegging, controls or any combination of these and other factors, as well as responsive to changes in domestic, international, political, social, and economic environments. Additionally, due to worldwide economic uncertainty, the availability and cost of funds for production and other expenses have become increasingly difficult, if not impossible, to project. These changes and events may materially affect our financial performance.

12. Our auditors’ opinion on our December 31, 2014 financial statements includes an explanatory paragraph in respect to there being substantial doubt about our ability to continue as a going concern.

We have incurred an accumulated deficit of $18,946,856 as of December 31, 2014. Our financial statements do not include any adjustments relating to the recoverability and classification of recorded assets, or the amounts of and classification of liabilities that might be necessary in the event the Company cannot continue in existence. We anticipate generating losses for at least the next 12 months. Therefore, there is substantial doubt about our ability to continue operations in the future as a going concern. We will need to obtain additional funds in the future. Our plans to deal with this cash requirement include loans from existing shareholders, raising additional capital from the private sale of our equity securities or entering into a strategic arrangement with a third party. If we cannot continue as a viable entity, our shareholders may lose some or all of their investment in our company.

13. If we do not maintain the property lease payments on our properties, we will lose our interest in the properties as well as losing all monies incurred in connection with the properties.

We have two land packages in Alberta, Canada that were acquired through auction directly from the Government of Alberta. The land packages are made up of a number of underlying individual leases. All of our leases require annual lease payments to the Alberta provincial government. See Item 4.D for a more detailed description of the property obligations. If we do not continue to make the annual lease payments, we will lose our ability to explore and develop the properties and we will not retain any kind of interest in the properties.

14. We may not be able to compete with current and potential exploration companies, some of whom have greater resources and experience than we do in locating and commercializing oil and natural gas reserves.

The natural gas and oil market is intensely competitive, highly fragmented and subject to rapid change. We may be unable to compete successfully with our existing competitors or with any new competitors. We compete with many exploration companies that have significantly greater personnel, financial, managerial, and technical resources than we do. This competition from other companies with greater resources and reputations may result in our failure to maintain or expand our business.

15. We expect losses to continue in the future because we have no oil or gas reserves and, consequently, no revenue to offset losses.

Based upon the fact that we currently do not have any oil or gas reserves, we expect to incur operating losses in the next 12 months. The operating losses will occur because there are expenses associated with the acquisition, exploration, and development of natural gas and oil properties that do not have any income-producing reserves. Failure to generate revenues may cause us to go out of business. We will require additional funds to achieve our current business strategy and our inability to obtain additional financing will interfere with our ability to expand our current business operations.

16. Because we are in the exploration stage of operations of our business, our securities are considered highly speculative.

We are in the exploration stage of our business. As a result, our securities must be considered highly speculative. We are engaged in the business of exploring and, if warranted and feasible, developing natural gas and oil properties. Our current properties are without known reserves of natural gas or oil. Accordingly, we have not generated any revenues nor have we realized a profit from our operations to date and there is little likelihood that we will generate any revenues or realize any profits in the short term. Any profitability in the future from our business will be dependent upon locating and developing economic reserves of natural gas and oil, which itself is subject to numerous risk factors as set forth herein. Since we have not generated any revenues, we will have to raise additional funds through loans from existing shareholders, the sale of our equity securities or strategic arrangement with a third party in order to continue our business operations.

17. Since our Directors work for other natural resource exploration companies, their other activities could slow down our operations or negatively affect our profitability.

Our Officers and Directors are not required to work exclusively for us and they do not devote all of their time to our operations. In fact, our Directors work for other natural resource exploration companies. Therefore, it is possible that a conflict of interest with their time may arise based on their consulting or employment by such other companies. Their other activities could slow our operations and may reduce our financial results because of the slowdown in operations. It is expected that each of our Directors will devote approximately 1 hour per week to our operations on an ongoing basis and when required, will devote whole days and even multiple days at a stretch when property visits are required or when extensive analysis of information is needed.

RISKS RELATING TO OUR COMMON SHARES

18. We may, in the future, issue additional common shares, which would reduce our investors’ percentage of ownership and may dilute our share value.

Our Articles of Incorporation authorize the issuance of an unlimited number of common shares without par value and an unlimited number of preferred shares without par value. The future issuance of our unlimited authorized common shares may result in substantial dilution in the percentage of our common shares held by our then existing shareholders. We may value any common shares issued in the future on an arbitrary basis. The issuance of common shares for future services or acquisitions or other corporate actions may have the effect of diluting the value of the shares held by our investors, and might have an adverse effect on any trading market for our common shares.

19. Our common shares are subject to the "Penny Stock" Rules of the SEC and we have no established market for our securities, which make transactions in our stock cumbersome and may reduce the value of an investment in our stock.

Section 15(g) of the Securities Exchange Act of 1934, as amended, and Rule 15g-2 promulgated thereunder by the Commission require broker-dealers dealing in penny stocks to provide potential investors with a document disclosing the risks of penny stocks and to obtain a manually signed and dated written receipt of the document before effecting any transaction in a penny stock for the investor's account. These rules may have the effect of reducing the level of trading activity in the secondary market, if and when one develops. Potential investors in the Company’s common stock are urged to obtain and read such disclosures carefully before purchasing any shares that are deemed to be "penny stock." Moreover, the Securities and Exchange Commission has adopted Rule 15g-9 which establishes the definition of a "penny stock," for the purposes relevant to us, as any equity security that has a market price of less than USD $5.00 per share or with an exercise price of less than USD $5.00 per share, subject to certain exceptions. For any transaction involving a penny stock, unless exempt, the rules require:

	·	That a broker or dealer approve a person's account for transactions in penny stocks; and
	·	That the broker or dealer receive from the investor a written agreement to the transaction, setting forth the identity and quantity of the penny stock to be purchased.

In order to approve a person's account for transactions in penny stocks, the broker or dealer must:

	·	Obtain financial information and investment experience objectives of the person; and
	·	Make a reasonable determination that the transactions in penny stocks are suitable for that person and the person has sufficient knowledge and experience in financial matters to be capable of evaluating the risks of transactions in penny stocks.

The broker or dealer must also deliver, prior to any transaction in a penny stock, a disclosure schedule prescribed by the Commission relating to the penny stock market, which, in highlight form sets forth:

	·	The basis on which the broker or dealer made the suitability determination; and
	·	That the broker or dealer received a signed, written agreement from the investor prior to the transaction.

Generally, brokers may be less willing to execute transactions in securities subject to the "penny stock" rules. This may make it more difficult for investors to dispose of our common shares and may cause a decline in the market value of our stock.

Pursuant to the Penny Stock Reform Act of 1990, broker-dealers are further obligated to provide customers with monthly account statements. Compliance with the foregoing requirements may make it more difficult for investors in the Company's stock to resell their shares to third parties or to otherwise dispose of them in the market or otherwise.

20. We are a “foreign private issuer” and you may not have access to the information you could obtain about us if we were not a “foreign private issuer”.

We are considered a "foreign private issuer" under the Securities Act of 1933, as amended. As a foreign private issuer, we will not have to file quarterly reports with the SEC nor will our Directors, Officer and 10% stockholders be subject to Section 16 of the Exchange Act. As a foreign private issuer, we will not be subject to the proxy rules of Section 14 of the Exchange Act. Furthermore, Regulation FD does not apply to non-U.S. companies and will not apply to us. Accordingly, you may not be able to obtain some of the information about us that you could obtain if we were not a “foreign private issuer”.

21. Because we do not intend to pay any cash dividends on our Common shares, our stockholders will not be able to receive a return on their shares unless they sell them.

We intend to retain any future earnings to finance the development and expansion of our business. We do not anticipate paying any cash dividends on our common shares in the foreseeable future. Unless we pay dividends, our stockholders will not be able to receive a return on their shares unless they sell them.

22. We may become a passive foreign investment company, or PFIC, which could result in adverse U.S. tax consequences to U.S. investors.

If we are a “passive foreign investment company” or “PFIC” as defined by Federal tax laws, U.S. Holders will be subject to U.S. federal income taxation under one of two alternative tax regimes at the election of each such U.S. Holder. Federal tax laws define a PFIC as a corporation that is not formed in the United States and either (i) 75% or more of its gross income for the taxable year is “passive income”, which generally includes interest, dividends and certain rents and royalties or (ii) the average percentage, by fair market value (or, if we elect, adjusted tax basis), of its assets that produce or are held for the production of “passive income” is 50% or more. Whether we are a PFIC in any year and the tax consequences relating to PFIC status will depend on the composition of our income and assets, including cash. U.S. Holders should be aware, however, that if we become a PFIC, we may not be able or willing to satisfy record-keeping requirements that would enable U.S. Holders to make an election to treat us as a “qualified electing fund” for purposes of one of the two alternative tax regimes applicable to a PFIC, which would result in adverse tax consequences to our shareholders who are U.S. citizens.

23. Because we are organized under the Canada Business Corporations Act and all of our assets and certain of our Officers and Directors are located outside the United States, it may be difficult for an investor to enforce judgments obtained against us or our Officers and Directors within the United States.

All of our assets are located outside of the United States and we do not currently maintain a permanent place of business within the United States. In addition, certain of our Directors and Officers are nationals and/or residents of countries other than the United States, and all or a substantial portion of such persons' assets are located outside the United States. As a result, it may be difficult for an investor to effect service of process or enforce within the United States any judgments obtained against us or our Officers or Directors, including judgments predicated upon the civil liability provisions of the securities laws of the United States or any state thereof. In addition, there is uncertainty as to whether the courts of Canada would recognize or enforce judgments of United States courts obtained against us or our Directors and Officers predicated upon the civil liability provisions of the securities laws of the United States or any state thereof. There is even uncertainty as to whether the Canadian courts would have jurisdiction to hear original actions brought in Canada against us or our Directors and Officers predicated upon the securities laws of the United States or any state thereof.

Item 4. Information on the Company

A. History and Development of Strata Oil & Gas Inc.

Strata Oil & Gas Inc. is a company principally engaged in the acquisition and exploration of oil and gas properties. We were incorporated under the laws of the State of Nevada on November 18, 1998 and commenced operations in January 1999. We completed our initial public offering in February 2000. The Company operates in the oil and gas industry with a focus on Canada’s carbonate-hosted bitumen deposits. The Company has interests in a total of 18 oil sands leases located in Northern Alberta, Canada.

Continuance to Canada

We are presently incorporated under the Canada Business Corporations Act. On April 22, 2003, the Company filed a registration statement to effect a continuation of our corporate jurisdiction from the State of Nevada to Canada on Form S-4 with the United States Securities and Exchange Commission (SEC). The Form S-4 was declared effective on or about July 7, 2004. On September 13, 2004, Strata filed a Form 8-A with the SEC registering its class of common shares under Section 12(g) of the Exchange Act.

Discontinued Operations

Until the end of June 2005, the Company had developed software that was designed to allow users to interface with and manage databases and customer relationships. On June 29, 2005 a majority of the Company’s shareholders approved a change in the business of the Company from software development to oil and gas exploration.

B. Business Overview

Refer to Item 4.A “History and Development of Strata Oil & Gas Inc." for information regarding the Company’s history and business activities.

BUSINESS DESCRIPTION

The Company currently has interests in oil sands properties located in the Peace River and Wabiskaw areas of Northern Alberta, Canada.

The Company is currently engaged in the acquisition exploration and if warranted and feasible development of oil and gas properties. The Company’s oil sands interests are unproven and there is no assurance that a commercially viable oil or gas deposit exists on any of its properties. Further evaluation will be required on each property before a final evaluation as to the economics and legal feasibility of the property is determined.

The Company originally had an interest in 43 oil sands leases in northern Alberta, Canada. In December 2010, the Company sold 25 of its oil sands leases to an Alberta company. As of December 31, 2014 the Company currently has interests in oil sands properties located in the Peace River and Wabiskaw areas of Northern Alberta, Canada including 17 leases in the Peace River oil sands area and one lease in the Athabasca oil sands area.

MATERIAL EFFECTS OF GOVERNMENT REGULATION

Development, production and sale of natural gas and oil in Canada are subject to extensive laws and regulations, including environmental laws and regulations. The oil and gas leases currently held by the Company are owned by the Province of Alberta and are managed by the Department of Energy. We may be required to make large expenditures to comply with environmental and other governmental regulations. Matters subject to regulation include:

	·	location and density of wells
	·	the handling of drilling fluids and obtaining discharge permits for drilling operations
	·	accounting for and payment of royalties on production from state, federal and Indian lands
	·	bonds for ownership, development and production of natural gas and oil properties
	·	transportation of natural gas and oil by pipelines
	·	operation of wells and reports concerning operations
	·	taxation

Under these laws and regulations, we could be liable for personal injuries, property damage, oil spills, discharge of hazardous materials, remediation and clean-up costs and other environmental damages. Failure to comply with these laws and regulations may also result in the suspension or termination of our operations and subject us to administrative, civil and criminal penalties. Moreover, these laws and regulations could change in ways that substantially increase our costs. Accordingly, any of these liabilities, penalties, suspensions, terminations or regulatory changes could have a material adverse affect on our financial condition and results of operations which could potentially force us to cease our business operations.

SEASONALITY, DEPENDENCY UPON PATENTS, LICENSES, CONTRACTS, PROCESSES, SOURCES AND AVAILABILITY OF RAW MATERIALS

Certain of the Company’s properties are in remote locations and subject to significant temperature variations and changes in working conditions. It may not be possible to actively explore the Company’s properties in Alberta throughout the year due to seasonal changes in the weather. If exploration is pursued at the wrong time of year, the Company may incur additional costs to address issues relating to the weather.

Shortages or an increase in cost of drilling rigs, equipment, supplies or personnel could delay or interrupt our operations, which could impact our financial condition and results of operations. Drilling activity in the geographic areas in which we conduct drilling activities may increase, which would lead to increases in associated costs, including those related to drilling rigs, equipment, supplies and personnel and the services and products of other vendors to the industry. Increased drilling activity in these areas may also decrease the availability of rigs. We do not have any contracts with providers of drilling rigs and consequently we may not be able to obtain drilling rigs when we need them. Therefore, our drilling and other costs may increase further and necessary equipment and services may not be available to us at economical prices.

COMPETITION

The natural gas and oil exploration industry is intensely competitive, highly fragmented and subject to rapid change. We may be unable to compete successfully with our existing competitors or with any new competitors. We compete with many exploration companies that have significantly greater personnel, financial, managerial, and technical resources. This competition from other companies with greater resources and reputations may result in our failure to maintain or expand our business.

C. Organizational Structure

The Company is not part of a group and has no subsidiaries.

D. Property, Plant and Equipment

CORPORATE OFFICES

We do not own any real property. Our corporate offices are located at 10010 - 98 Street, PO Box 7770, Peace River, Alberta T8S 1T3. We believe that the facilities will be adequate for the foreseeable future.

OIL SANDS LEASES

The Company currently has an interest in 18 oil sands leases in northern Alberta, Canada of which 17 of the leases are located in the Peace River oil sands area and 1 lease is located in the Athabasca oil sands area.

Oil Sands Background

“Oil Sands” refers to unconsolidated, bitumen-saturated sands containing varying amounts of clay and rock material. The bitumen content refers to a heavy, viscous crude oil that generally does not flow under natural reservoir conditions. As a result, it cannot be recovered from a conventional well the way lighter oil is most often produced. The oil sands are contained in three major areas beneath an approximate 140,800 square kilometers (54,363 square miles) of north-eastern Alberta - an area larger than the state of Florida. As of December 2002, according to the Alberta Department of Energy, these three areas, Athabasca/Wabiskaw, Peace River, and Cold Lake, contained 1.6 trillion barrels of bitumen in-place, of which 174 billion barrels are proven reserves that can be recovered using current technology.

These deposits contain a significant amount of oil but until recently the cost of extraction has created a barrier to economic development. Extraction of oil from oil sands requires technologically intensive activity and the input of significant amounts of energy to exploit the oil sands deposits. There are two main types of oil sands production methods: mining and in-situ. Oilsands mining is accomplished using an open pit operation whereby the oil sands are dug up and trucked to a processing facility. For oil sands reservoirs too deep to support economic surface mining, some form of in-situ recovery is required to produce bitumen. In-situ production is similar to that of conventional oil production where oil is recovered through a well. The Alberta Energy and Utilities Board estimates that 80 percent of the total bitumen ultimately recovered will be with in-situ techniques. Numerous in-situ technologies have been developed that apply thermal energy to heat the bitumen and allow it to flow to the well bore.

There are some oil sands reservoirs where primary or “cold” production is possible. The lighter bitumen in these areas can flow towards a well and bitumen production can be enhanced by the co-production of sand, thereby creating a down hole cavity around the well bore which facilitates the flow of oil towards the well. This type of production technology is commonly referred to as “Cold Heavy Oil Production with Sand” (“CHOPS”). While this type of bitumen is marginally lighter and less viscous than the conventional bitumen found in mineable and other in-situ reserves, it is also slightly heavier than the conventional “Heavy Oil” reservoirs produced in the “heavy oil belt” region, located around the central Alberta - Saskatchewan border. Another production technology, which may be suitable for some of the lighter oil sands reservoirs, is the use of horizontal well bores. Horizontal production wells, which have been drilled up to more than 2 kilometers away from their surface locations, have been successfully applied to cold in-situ bitumen production, where it is suitable. In general, open pit oil sands mines are found in central Athabasca deposits, while in-situ bitumen production technology is used in the Cold Lake, south Athabasca, and Peace River deposits, where the overburden thickness exceeds 50 meters.

Oil in oil sands is found mainly in high porosity quartz arenites to arkosic sands that cover large areas and lie up-dip from the purported source rocks to the southwest. There are also vast amounts of heavy oil as well in fractured carbonate rocks of 10-14% porosity underlying a large triangular region of north central Alberta. In addition, there is a large amount of heavy oil in a series of thinner blanket sands and channel sands extending all the way from Suffield, Alberta to zones overlying the Cold Lake Oil Sands near Bonnyville, and extending well into Saskatchewan. The latter deposits called the ‘heavy oil belt” are the sites of the most development attention because the oil is less viscous and it can be produced using either CHOPS or horizontal well technology.

The source rocks for the oil sands are from the Cretaceous and Jurassic shales in the Alberta Syncline. Rapid sedimentation of organic rich argillaceous material caused large flow volumes to be generated as the result of compaction. Deep burial of the kerogeneous source rocks allowed organic diagenesis to occur resulting in the generation of oil and gas from the kerogen. The oil sands are 98% un-cemented (unconsolidated sandstones). The ingress of bitumen has essentially stopped diagenetic processes and the sands do show strong evidence of the early effects of pressure solution and re-crystallization but true cementation is quite rare as are significant calcite cemented zones.

Carboniferous Oil Sands

Strata has focused its efforts on carbonate-hosted bitumen sands. The carbonates are the next challenge in the Alberta oil sands industry. Like oil sands two decades ago, carbonates represent an enormous and relatively untapped petroleum resource. The means for producing bitumen from carbonates is still being studied. The nature of the carbonate triangle in Alberta tends to vary and there is unlikely to be a single one-size -fits-all strategy for production. Cold production may be possible in some areas although in most cases production requires an in-situ treatment. Various technologies have been tested and others considered, including similar technologies to those employed in oil sands (cyclic steam, SAGD, etc.). Bitumen carbonates are still being studied, and as yet there are several techniques which may prove to be effective. We are in the process of determining the most efficient means of producing the bitumen from our Peace River project.

Carbonate oil sands are an unconventional resource that remains almost untapped. While much of the world now knows about Alberta’s vast oil sands resource, many people are unaware that a bitumen resource of similar magnitude is locked in carbonate rock. According to a report by Petroleum Technology Alliance Canada (PTAC), 26% of Alberta’s bitumen resources are contained in carbonate rather than sand formations. One northern Alberta carbonate formation alone — the Devonian-age Grosmont complex — has bitumen volumes in place comparable to the huge Athabasca oil sands deposit. This comparison is made in the 176-page official history of the Alberta Oil Sands Technology and Research Authority (AOSTRA), the long-since disbanded provincial agency set up in 1974 to promote bitumen recovery technologies. The history devotes four well-illustrated pages to bitumen carbonates. The resource received serious attention during the AOSTRA years with a series of pilot tests running in the Grosmont formation between 1975 and 1987. However, oil prices fell and funding was cut. The remotely located and little known bitumen carbonates were largely forgotten until Royal Dutch Shell plc paid nearly $500 million for leases in 2006.

Contained in a roughly triangular 70,000 square-kilometer area of northern Alberta called the Carbonate Triangle, the deposits may be the most technically challenging of the province’s bitumen resources. The basic difference between oil sands and bitumen carbonates is the former is bitumen mixed with unconsolidated sand, which can be either mined or produced from wells. The latter, as the name implies, is bitumen in carbonate rock — both dense limestone and heavily karsted rock. Grosmont bitumen is even heavier than the Athabasca bitumen and the reservoir is extremely variable, meaning that a single recovery method is unlikely to work throughout the formation. The lack of understanding of the heterogeneous nature of the reservoir is the main hurdle for developing successful bitumen recovery schemes. The bitumen is contained in a dual porosity system — both in the vugs (cavities or fractures) and in the rock matrix itself. The vugs could potentially be good news in that they could conceivably improve permeability once the viscosity of the bitumen is raised by heat or other means, but bad news if they serve as channels for steam to escape from the area of interest. In the karsted areas, these irregular cavities and tunnels are often the diameter of a man’s arm, and sometimes much larger. According to the PTAC review of the pilot results, challenges of drilling through this karsted rock include the potential for loss of drilling fluids into the formation, and problems with the placement of cement to maintain a strong well-to-formation bond.

DROWNED AREA OIL SANDS LEASE

Acquisition of Interest

On September 7, 2005 the Company acquired a 100% interest in Alberta Oil Sands Lease #7400100011 (the “Drowned Property’). The rights to the Drowned Property were acquired for a payment of CDN $25,000 (USD $20,635) as well as other closing costs of CDN$9,874 (USD $8,150). The Drowned Property covers 512 hectares of land in the Drowned Area of the Wabiskaw oil sands in the West Athabasca area of Northern Alberta. The lease gives the Company the right to explore the Drowned Property covered by the lease.

Strata's acquisition of the Drowned Property lease includes an overriding 4% royalty agreement with the vendor. The royalty is to be paid on a well-to-well basis and is payable on all petroleum substances produced by any well on the Property. In addition, the Company must pay the Province of Alberta CDN $1,792 (USD $1,798) per year to maintain its right to the lease. The lease is subject to a royalty payable to the Government of Alberta.

Alberta's project-based generic oil sands royalty regime operates on the principle of revenue minus cost. Royalty is paid at one of two rates, depending on the project’s financial status. The deciding factor is the project’s payout date. A project has “reached payout” once its cumulative revenues have exceeded its cumulative costs. Before the payout date, the applicable royalty is 1% of the project’s gross revenue. This low rate recognizes the high costs, long lead times and high risks associated with oil sands investment. It prevents undue strain on the developer’s financial resources during the most critical, start-up stages of the project. After the payout date, the applicable royalty is the greater of 1% of the project’s gross revenue or 25% of the net revenue for the period.

Location

The Drowned Property lies near the southern edge of the Wabiskaw Heavy Oil/Oil sands field in west Athabasca approximately 45km south of the town of Wabiskaw or 60km Northeast of Slave Lake.

Lease Number	Hectares	Townships	Range	Section

7400100011	512	75, 76	23	1 and 36

Drowned Project Lease Information

The Drowned Property is comprised of a single lease with the Government of the Province of Alberta, Canada. The lease is a fifteen-year lease and expires on October 4, 2015.

Lease Number	Hectares	Rent / Hectare	Annual Minimum Lease Payments

7400100011	512	CDN $3.50 (USD $3.02) per year	CDN $1,792 (USD $1,545) per year

Regional Geology

Regionally, the Wabiskaw Reservoir consists of three overlapping en-echelon sand bodies interpreted as shoreface sand which coarsen upwards from shale to fine sand. The three bodies are informally referred to as Wabiskaw “A” Sand, Wabiskaw “B” Sand, and Wabiskaw “C” Sand. The three bodies are separated from each other by shales and each has proven to be correlatable and mappable over a wide area. All three bodies contain bitumen, but only the bitumen sand of the Wabiskaw “A” is being cold produced at the present time. The “B” and “C” are generally thinner and contain smaller bitumen accumulations.

Gas and water are also significant components of the reservoir fluids in the Wabiskaw sands. Several associated gas fields are currently in production. There may be a distinct basal water leg below the bitumen. This is especially true in the southwestern part of the Wabiskaw reservoirs.

The deposit lies above the western part of the Athabasca oil sands and extends westward somewhat beyond the McMurray Formation edge. In many regions, the Wabiskaw is oil rich and it overlies the McMurray forming two stacked reservoirs. Detrital matter arrived mainly from the west but mixed with a small component of sediments from the shield. The bitumen is highly viscous and is at a depth of 100 to 700 meters. The Wabiskaw is classified as the lowest Member of the Clearwater Formation and therefore overlies the McMurray Formation. The reservoir and the thickness of oil-saturated material vary from 0 to 10 meters.

Property Geology

Several pre-existing bore holes indicate that neither the Wabiskaw “A” sand nor the Wabiskaw “B” sand is present on the Company’s Drowned Property, although it appears that 0 to 4 meters of a thin bitumen-bearing Wabiskaw “C” sand may be present. In addition, the McMurray Formation is present beneath the Wabiskaw and fills a local north-south oriented valley system incised into the older limestone basement. These McMurray valley filled sediments appear to be complex, consisting mainly of water-bearing silts and clays, and hold only minor, discontinuous, bitumen-bearing sands of an unknown quality. The Wabiskaw and McMurray sands lie at a depth of 550 to 600 meters and the Grand Rapids reservoir lies at a depth of 425 to 500 meters.

Previous Work

Historically, the Drowned Project has had four wells drilled on it by companies owning the gas exploration rights. The geophysical well logs demonstrate the presence of bitumen in all four wells, one of which shows the presence of oil sands.

Planned Work by the Company for 2015

The Company plans to continue focusing its exploration resources on its Peace River Property. The Drowned Property lease which is due to expire in October 2015 will be reviewed prior to its expiration.

PEACE RIVER OIL SANDS LEASES

The following are two maps showing the location of the Company’s 17 oil sands leases in the Peace River region of northern Alberta, Canada.

Acquisition of Interest

The Company has entered into a series of leases in multiple transactions with the Province of Alberta in the Peace River area of Alberta, Canada (the “Peace River Property”). All of the leases were acquired through a public auction process that requires the Company to submit sealed bids for land packages being auctioned by the provincial government. Upon being notified that it has submitted the highest bid for a specific land parcel the Company immediately pays the Government the bid price and enters into a formal lease with the government. The bid price includes the first year’s minimum annual lease payments. The specific transactions entered into by the Company are as noted below.

Date	Number of Leases	Land Area (Hectares)		Annual Minimum Lease Payments

June 15, 2006	3		4,864	CDN $17,024 / USD $14,675
October 19, 2006	4		3,584	CDN $12,544 / USD $10,813
November 2, 2006	4		5,632	CDN $19,712 / USD $16,992
January 11, 2007	4		4,608	CDN $16,128 / USD $13,903
January 24, 2007	2		2,304	CDN $8,064 / USD $6,951
	17		20,992	CDN $73,472 / USD $63,332

The Peace River Property consists of a total of 20,992 hectares of land in a region of northern Alberta known as Peace River. The leases are subject to royalties payable to the Government of Alberta. Alberta's project-based generic oil sands royalty regime operates on the principle of revenue minus cost. Royalty is paid at one of two rates, depending on the project’s financial status. The deciding factor is the project’s payout date. A project has “reached payout” once its cumulative revenues have exceeded its cumulative costs. Before the payout date, the applicable royalty is 1% of the project’s gross revenue. This low rate recognizes the high costs, long lead times and high risks associated with oil sands investment. It prevents undue strain on the developer’s financial resources during the most critical, start-up stages of the project. After the payout date, the applicable royalty is the greater of 1% of the project’s gross revenue or 25% of the net revenue for the period.

Location

The Peace River Property lies in the Peace River oil sands field in Alberta approximately 40 to 50 kilometers northeast of the town of Peace River. These holdings are situated near Cadotte Lake.

Peace River Project Lease Information

The Peace River Property interest (hereinafter referred to as “Cadotte West”, “Cadotte Central”, “Cadotte East” or collectively the “Cadotte Leases” is comprised of 17 leases with the Government of the Province of Alberta, Canada. All of the leases are for a 15-year term, require minimum annual lease payments, and grant the Company the right to explore for potential oil sands opportunities on the respective lease.

Regional Geology

The Peace River Cretaceous clastic reservoir consists of a complex stratigraphy similar in nature to the Athabasca Deposit to the east. These are thought to comprise fossil estuarine systems where the best reservoirs are contained in tidal inlet and barrier sands. Secondary reservoir targets may be tidal delta, bayhead delta, tidal channel, and tidal flat sands. The Peace River Carboniferous reservoir consists of platform sediments with relatively few reef building organisms. Structurally, the Peace River strata dip to the southwest and the elevation of the bitumen-bearing interval lies between 50 and 100 meters below sea level or at a depth of between 680 to 790 meters below the surface.

Property Geology (Cadotte Leases)

Strata has focused its efforts on the bitumen resources contained in the Debolt/Elkton carbonate Carboniferous Formation and the Bluesky/Gething clastic Cretaceous Formation in the Cadotte area. In particular, our exploration programs to date have focused on 50 sections in the Cadotte area located in Townships 86 and 87, Ranges 18, 19 and 20. (the “Target Area”).

The nature of the geology of the carbonate sequence in the Target Area has a significant influence on the distribution of the bitumen resource. The principal reference source for this section is the Alberta Research Council’s publication, “Geological Atlas of the Western Canada Sedimentary Basin”. The sequence that hosts the bitumen deposits is the Rundle Group of Lower Carboniferous age. The Rundle Group in this area includes three stratigraphic units which, in ascending order, are the Pekisko, Shunda and Debolt Formations. From place-to-place the Debolt Formation may also include another distinct unit, the Elkton Member. In the Cadotte Lease area, the Elkton Member is usually present, as long as the overlying unconformity with the Cretaceous sequence has not eroded the entire Debolt Formation sequence. Although there are many intervals that are bitumen enriched in the Rundle sequence in the Cadotte Lease area, the principal enrichment zones occur in the Elkton Member, the upper half of the Debolt but usually not right at the top of the formation and, to a lesser extent, in the Shunda Formation. The high grade zones of enrichment are those that occur in the Elkton Member and the Debolt Formation.

A Cretaceous clastic sequence that includes the Gething and Bluesky Formations at the base, unconformably overlies the Carboniferous rocks in this area. All the beds dip gently to the west with those lying below the unconformity having a somewhat greater dip than those above it. This causes the sequence below the unconformity to be eroded to a greater degree to the east and to be less complete, compared with the west. These westerly dips are the result of post-depositional tectonic events and do not reflect the original orientation of the accumulation of sediment. The Carboniferous sequence of the Rundle assemblage accumulated as a result of a series of prograding events that developed in a southerly to southwesterly direction.

The Carboniferous sequence mainly includes platform sediments that show generally shallower-water characteristics up-section. In a basinward direction the depositional facies proceed from beach and lagoonal environments through shoals of the shelf margin to marine basin muds. The lithologies that result include high energy siliciclastics of the beach environment, through various types of carbonates on the platform and its slope to shale in the deep marine environment. There even appear to be beds present that have the character of unconsolidated coarse sediments. Several transgressive events therefore resulted in the accumulation of clastic sediments interbedded with carbonate units.

The carbonate units included relatively few reef building organisms and thus there was little tendency for irregular geological bodies such as reefs to form in this sequence in this area. From one well to the next the regular nature of the deposition that took place at this time is apparent and it is relatively easy to show the correlation that exists between the same units in adjacent wells in the target area. This feature of regular bed continuity is in strong contrast to the variability of the clastic units of the overlying Cretaceous sequence as seen in the Athabasca region.

It is also most noteworthy that the bitumen enrichment is strongly influenced by the bedded nature and continuity of the sediments. It is readily possible in many cases to show the same details of the enriched sequence in adjacent wells even when they are spaced a kilometer or more apart. This has a very strong impact on the selection of data separation distances for the classification of resources; in this sequence an equivalent assurance of existence is achieved with much wider spacing of wells than that used in the classification of bitumen resources for the Cretaceous surface mineable oil sand deposits presently being explored and developed near Fort McMurray.

Previous Work

During the winter drill season of 2006 – 2007, Strata drilled four wells on the Cadotte leases. Three of these wells were within the Cadotte Central Target Area and one was in the Cadotte East leases. All of the wells were drilled and cored. Three wells were drilled with cores in the Cadotte Central Target Area, two of which were cased allowing for production testing with the ability to re-enter these wells for future testing. The other well was abandoned due to drilling fluid losses during drilling which did not allow the well to be cased for testing in the future. The fourth well drilled in the Cadotte East location was cored and cased. Due to natural gas flowing from the well, to which the Company did not have the rights to, additional borehole tests were not conducted. The cores of all of these wells were tested and examined in a laboratory in Calgary. The results of these tests were that cold production was not viable. However, the results indicated that the bitumen would flow at approximately 85°C. These results will allow the Company to explore different means of extraction in addition to steam.

Former leaseholders have drilled wells on and around the Company’s Target Area. Geophysical well logs are of variable quality but generally consist of a full suite of tools to evaluate the potential reservoirs. With respect to available drilling data, the leases of the Target Area are drilled at an average spacing of one well per section. However, not all of these existing wells were drilled to investigate the sequence located on the Company’s Cadotte leases. The effective average spacing with wells that have penetrated the Carboniferous sequence is approximately 0.8 wells per section. This spacing is from twenty-three wells on or immediately adjacent to the leases. There are an additional two hundred nineteen wells in the surrounding area, the data from which has also been referenced and inspected by the Company to assist with its evaluation of the Cadotte leases.

However, the quality of the data from the wells of different vintage is quite variable. Several of the wells were drilled in the 1950’s. The drilling records and logs for these wells are sometimes poor or absent or they may be less complete than those of more recently drilled wells. A database search was done to identify higher quality data which was restricted to wells drilled since 1970 and this, plus the new Strata wells was used as the primary reference data. A total of eighteen wells of this vintage are located on or immediately adjacent to the lease blocks. The well log data from these wells is the primary source of information on the leases available for the present evaluation but this was supplemented by high quality data from a further thirty-nine more distant wells in the area.

In the United States, registrants, including foreign private issuers like us, are required to disclose proved reserves using the standards contained in Rule 4-10(a) of the United States Securities and Exchange Commission’s (“SEC”) Regulation S-X. The Company has no proved reserves at this time.

Cadotte Central – Contingent Bitumen Resource

The Company completed the drilling of its first four wells in the winter drilling season of 2006 – 2007. Strata had engaged Norwest Corporation (”Norwest”) of Calgary, Alberta, Canada to assist Strata with the planning and undertaking of its exploration of the Cadotte Central leases. On August 16, 2007 Norwest completed a technical report titled Evaluation of In-Place Bitumen Resources – Cadotte Central Leases and on February 29, 2008 Norwest Questa Engineering Corporation (“Norwest Questa”) of Golden, Colorado completed a report titled Preliminary Feasibility Study of the Cadotte Central Leases, Alberta, Canada. On April 28, 2010 Norwest completed a follow up report titled Cadotte Project – Resource Reclassification 2013 Norwest Report. All of these reports are available to the public on the www.sec.gov web site. All discussion in this section is qualified by reference to the three reports above and readers are advised to read the three technical reports in their entirety.

Evaluation of In-Place Bitumen Resources – Cadotte Central Leases – August 16, 2007

The study was designed to comply with the requirements of National Instrument 51-101 and the resource classification scheme and criteria elaborated in Volume 1, of the Canadian Oil and Gas Evaluation Handbook. Recoverable bitumen volumes were not addressed in this report because no estimate of the recovery factor was available at the time. Mr. Geoff Jordan, P. Geol., former Senior Vice President of Norwest Corporation and a qualified person as defined by National Instrument 51-101 was responsible for the preparation of the technical information in the report.

The amount of exploration drilling and testing on the Cadotte Target Area was sufficient for that part of the Peace River Oil Sand deposit to be classified as a Discovered Resource (the classification system was subsequently changed such that the Discovered Resource would now be called Discovered Petroleum Initially In-Place (PIIP)). The classification of the Discovered Resource into Low, Best ("Most Likely") and High categories was based on the following criteria:

	·	The Low Estimate includes all of the material that has a minimum grade of 8 wt% and a minimum thickness of 10 m;

	·	The Best (Most Likely) Estimate includes all of the material that has a minimum grade of 8 wt% but no minimum thickness; and

	·	The High Estimate includes all of the material without any grade or thickness constraint. Hence the latter is an estimate of the original bitumen in place for the zones under investigation in the Cadotte Target Area.

The results of the different estimates for the Original Bitumen In Place (“OBIP”) are presented on the following table:

Effective OBIP for the Cadotte Area by Target Zone in millions of Stock Tank Barrels (MMSTB), (Using 8% wt Cut-off.)

Formation	Low Estimate	Best (Most Likely) Estimate	High Estimate
Bluesky/Gething	N/A	N/A	103
Debolt	1,443	1,500	1,503
Elkton	N/A	490	644
Total	1,443	1,990	2,251

In the Bluesky/Gething Formations the results indicate that there are some areas where grades above the threshold of 8 wt% occur but these are somewhat scattered and there are no areas where especially high grade results were found. At the same time, the ore thickness is generally relatively low.

It is important to note that the resource estimates presented in this report are made for quantities on an in-place basis. This is not an estimate of quantities that may be recovered. Such an estimate could not be made at the time because there was no reliable value available for the bitumen recovery factor that should be applied. Such a factor is determined as a result of the completion of various engineering tests and analyses.

The accuracy of resource estimates is, in part, a function of the quality and quantity of available data and of engineering and geological interpretation and judgment. Given the data available at the time this report was prepared, the estimates presented herein are considered reasonable. However, they should be accepted with the understanding that additional data and analysis available subsequent to the date of the estimates may necessitate revision. These revisions may be material. There is no guarantee that all or any part of the estimated resources of bitumen will be recoverable.

Neither Strata nor Norwest make any express or implied warranties or guarantees of any kind concerning this report; including without limitation any implied warranty of merchantability or fitness for a particular purpose. Specifically, neither Strata nor Norwest make any warranties or guarantees that any property identified in this report will produce oil and/or gas in any quantity, or that any property identified in this report will produce or receive any economic, commercial, or other benefit.

Readers of this 20-F are advised to read the August 16, 2007 report titled Evaluation of In-Place Bitumen Resources - Cadotte Leases, that is publicly available on the www.sec.gov web site and was filed by the Company on September 27, 2007 under cover of 6-K.

Preliminary Feasibility Study of the Cadotte Leases, Alberta, Canada – February 29, 2008

The preliminary feasibility report was prepared in compliance with Canadian National Instrument 51-101 guidelines for disclosure concerning oil and gas resources in Canada. NI 51-101 requires that the procedures and criteria of the Canadian Oil and Gas Evaluation Handbook (“COGE Handbook) be used for resource classification and these standards and criteria have been used in this report. In this case it has been found that the estimate of potentially recoverable bitumen in the Cadotte Target Area at the time of the report could not be classified as a Contingent Resource. The major factor was that there is no pilot project at the time that applied in-situ recovery methods to bitumen in a hardrock carbonate host that could be used as a demonstration of recoverability. This meant that existing pilot projects in clastic hosts, which have different physical characteristics from carbonates, had to be used for performance prediction. This additional risk prevented the “Contingent Resource” classification being made. The additional factors that also prevented classification as a Contingent Resource include:

	1.	A lack of a cost estimate for the full-field development and operation of a bitumen recovery and upgrading project;
	2.	Lack of permeability data for the target zones; and
	3.	Limited geologic and reservoir data samples for the target zones

The Norwest August 16, 2007 report resource estimate is classified as “Discovered Resources”, in accordance with the criteria and former classification scheme of the COGE Handbook. The current version of the COGE Handbook has re-titled “Discovered Resources” as “Discovered Petroleum Initially In Place” (“Discovered PIIP”). The Pre-Feasibility estimate prepared by Norwest Questa is compliant with the requirements of National Instrument 51-101 with respect to classifying the resource as Discovered PIIP. Dr. John D. Wright, Ph.D., P.E., who was President and Chief Engineer, of Norwest Questa Engineering Corporation at the time of the preparation of the Preliminary Feasibility, is a qualified person as defined by National Instrument 51-101. Dr. Wright supervised the preparation of the technical information in this report.

The analogy method was utilized to develop recovery factors that were applied to the OBIP estimates to obtain a low, most likely, and high estimate for potentially recoverable bitumen. Several projects using technology similar to that expected to be implemented on the Cadotte leases were used as analogies for a bitumen recovery method and a resultant range of recovery factors. Shell’s Carmon Project (“Carmon Creek”) was one of the primary analogies utilized by Norwest for the recovery factor estimates. Norwest reviewed the Carmon Creek Project and concluded that some bitumen bearing stratigraphy on Strata’s land correlates with the same stratigraphy at Carmon Creek. Over the last 25 years, Shell has tested numerous recovery methods at Peace River and has recently concluded that Horizontal Cyclic Steam (“HCS”) is the optimal recovery method for Carmon Creek. The Preliminary Feasibility Study for Cadotte is based on the application of that method of extraction, as well as the Shell Carmon Project well layout and designs which were obtained from various public disclosure reports.

A production schedule was developed for the Cadotte leases over the key Target Area of twenty nine sections. Each section, which has an area of one square mile, is about the same size as the Carmon Project pad and development block design. Each pad and development block includes 20 wells of 1,400 m length, each of which is about 600 m in the vertical direction and 800 m horizontally. In the design the pads are “brought on stream” over a four year build-up period. The development block sequence is implemented such that the highest grade and thickest ore blocks are addressed first as long as the local infrastructure is able to service those areas. During the main period of development, the daily production rate for the leases is about 56,000 barrels. The production life for this schedule exceeds 20 years. Cost estimates for this preliminary feasibility study were obtained from a review of public literature.

Based on the analogy method with an adjustment for difference between gross and effective OBIP calculations, Norwest Questa estimated the following recovery factors for application to the effective OBIP deterministic cases:

	·	17 percent for the Low estimate
	·	26 percent for the Most Likely estimate, and
	·	38 percent for the High estimate.

Norwest Questa then applied the estimated recovery factors shown above to the effective OBIP estimates from the August 16, 2007 report, which is the in-place Best estimate at an 8 wt% grade cut-off, to obtain the Low, Most Likely, and High Resource estimates for the Cadotte Area.

On April 28, 2010 Norwest issued a report upgrading the resource classification to “Contingent Resource” from “Discovered Resource”, in accordance with the criteria and former classification scheme of the COGE Handbook. The Resource Reclassification report prepared by Norwest is compliant with the requirements of National Instrument 51-101 with respect to classifying the resource as “Contingent”. Geoff Jordan, P. Geol., Senior Geologist at Norwest Corporation prepared the Resource Reclassification report, is a qualified person as defined by National Instrument 51-101.

With the Cadotte Recoverable bitumen quantity classified as a Contingent Resource, it is a requirement for reporting to identify and list the contingencies. These are as follows:

	·	The company will have to develop a suitable Debolt Formation carbonate Pilot to demonstrate the technical and commercial viability of operating any specific planned in situ recovery method for this project. The cost estimate for development of the project includes a provision for completing this work;

	·	The company will have to obtain all of the legal permits necessary for the initiation of the project and for construction and operation of it;

	·	The company will have to secure a suitable market for the bitumen;

	·	The company will have to ensure that all of the environmental requirements, including those that relate to water usage and disposal are satisfied.

The 2010 Norwest Corporation report modified the classification of the resources, and not the quantities, to reflect the following recoverable portion of the effective OBIP estimates:

Contingent Resource for the Cadotte Area by Target Zone in millions of Stock Tank Barrels (MMSTB)

Formation	Low Estimate	Most Likely Estimate	High Estimate
Bluesky/Gething	N/A	N/A	39
Debolt	245	390	571
Elkton	N/A	127	245
Total	245	517	855

In 2008 Norwest Questa conducted an initial economic evaluation of the Cadotte area, at a level of study consistent with that of a Preliminary Feasibility Study, based on the Most Likely potentially recoverable Discovered PIIP estimate of 517 MMSTB. Based on a forecast price of $65 per barrel and constant costs, this Preliminary Feasibility economic analysis indicated that the development of the Cadotte area was economically viable with a net present value (discounted at 10%) of cash flows before income taxes of about $1.2 billion.

In 2010 Norwest Corporation completed a revised sensitivity analysis based on three different oil prices. The assumptions utilized in the 2010 economic evaluation were based on a review of published public data for similar projects. The analogy method was originally utilized to develop recovery factors that were applied to the original bitumen-in-place estimates to obtain a low, most likely, and high estimate for potentially recoverable bitumen. Several projects using technology similar to that expected to be implemented on Strata's Cadotte Project were used as analogies for a bitumen recovery method and a resultant range of recovery factors. See the table below for the 2010 revised sensitivity analysis:

Revised 2010

Summary of Economic Evaluations

at Different Oil Price Assumptions ($US Billions)

Oil Price	Gross Oil Revenue	Net Investment	Total Operating Expenses	Crown Royalties	Cumulative Cash Flow	Cumulative Disc. (10%) Cash Flow	IRR
Constant $85 WTI	27.1	1.9	12.1	4.1	9.1	1.3	28%
Constant $75 WTI	22.2	1.9	12.1	2.4	5.8	0.6	20%
Constant $95 WTI	32.1	1.9	12.1	5.9	12.1	1.9	36%

Based on forecast prices and costs, this revised economic analysis indicates that the development of the Cadotte area is economically viable with a return on capital investment of 28% and Net Present Value (“NPV”) discounted at 10% of $1.3 billion. At a WTI crude oil price of $85 per barrel, the impact of the planned royalty change is only about a 1% reduction of return on capital investment. At a constant $75 per barrel WTI price, the return on capital investment is just over 20%. Based on the favorable results of the pre-feasibility and revised economic analysis, the Cadotte area warrants further evaluation including a pilot well test program and feasibility level project design and cost estimates.

This report is limited in scope to document only the potentially recoverable portion of the Contingent Resource, formerly referred to as Discovered Petroleum Initially In Place (Discovered PIIP), within the Target Area of the Cadotte properties. This report does not attempt to place a Fair Market Value on that resource portion.

Norwest Corporation reserves the right to revise its opinions of all estimates of resources if new information is deemed sufficiently credible to do so.

The accuracy of any estimate is a function of available time, data, geological engineering, commercial interpretation, and judgment. While the resource estimates presented herein are believed to be reasonable, they should be viewed with an understanding that additional analysis of new data may justify their revision and Norwest Corporation reserves the right to make such revisions.

Readers of this 20-F Annual Report are advised to read the February 29, 2008 report titled Preliminary Feasibility Study of the Cadotte Leases, Alberta, Canada, and the April 28, 2010 report titled Cadotte Project - Resource Reclassification that were filed under cover of Form 6-K on March 6, 2008 and December 23, 2010, respectively, and are publicly available on the www.sec.gov web site.

Cadotte West – Bitumen Resource

Strata's Cadotte West project is located on 22 sections northwest of Shell's Carmon Creek Project and is contiguous to the company's Cadotte Central property holdings in Peace River. Data from prior years drill logs in the area indicate the Bluesky/Gething, Debolt and Elkton ore zones are present on the lease. This same data reports bitumen in these ore zones.

Historical information obtained from logs in the area indicates the Net Thickness of the Bluesky/Gething ore zone in this region appears to range from about 10 m to 25 m. There are actually two ore zones in the Bluesky/Gething in this area and these appear to individually thicken and come together to the south. Additionally, the logs include confirmation of hydrocarbons in the cuttings samples and are noted to have fluorescence response for hydrocarbons. This does not show the grade but it shows that bitumen is present in the ore zone. The resistivity responses for hydrocarbons in the elastic interval are strong and this indicates that there is a good chance that the zone contains bitumen at ore grade concentrations.

The same logs indicate that the ore zone of the Debolt can be expected to be present throughout the Cadotte West Area. This zone appears to be 25 m to 30 m thick. The logs consistently record that the interval of the Debolt ore zone has "vuggy porosity". This is the same as the Debolt reported under Cadotte Central Target area. The records consistently record strong hydrocarbon fluorescence in this interval, and note "oil saturation" or "strong oil saturation" in the cuttings from well to well over this interval. This suggests that the bitumen ore potential of the zone in this area is much the same as that found in the Cadotte Central Target Area.

During 2014 the Company moved forward on planned initiatives as follows;

Completed a seismic study to evaluate the Cadotte West property for heavy-oil recovery using cold production.

Utilizing existing well and seismic data the study focused on different physical properties and technical aspects related to the identification of pools and fields on our lands. The initial interpretation of the geological structure at Cadotte West resulted in the identification of cold production targets which were then validated by seismic data. The Company's technical team has subsequently identified multiple drilling locations in order to test the extent to which the Bluesky Formation at Cadotte West has the fluid properties which permit the use of primary production methods. In light of the findings the Company redirected the focus of its available resources from further development of the Cadotte Central property to the Cadotte West property. The Company remains committed to the Cadotte Central development opportunity; however, it is management’s view that the favorable economics of potential cold production methods on the Cadotte West property warrant further validation.

Commenced initial planning and permitting activities needed to develop a drill program and continue exploration of the identified targets for the Cadotte West property.

The Company engaged specialized third party service provider(s) to assist with the development of a drill program which includes the submission of an Oil Sands Exploration plan, the ("OSE") to the Crown. Elements of an OSE application include, but are not limited to, mapping and locating services, sensitive areas, wildlife zones, historical work in the area, site access, environmental services, exploration operations detail, stake holders and first nation consultation and project management services. The OSE program approval was received in February 2015 granting the Company two years from the date of issue to conduct its exploration program.

Planned Work by the Company for 2015

When adequate funding can be assembled Strata intends to proceed with its drill exploration program and identified targets to test for cold production. The Company expects the short and long term funding of our oil and gas operations to be financed as in the past through equity in the form of private placements and warrant exercises. In addition we continue to work with potential partners to discuss potential funding arrangements which could facilitate the furtherance of our drill program.

Evaluation of Bitumen Resources – Cadotte Central and West Leases Technical Report – May 10, 2013

In 2013, Strata successfully completed the 51-101 compliant Technical Resource Evaluation of its Cadotte West and Cadotte Central holdings located in the Peace River region. The evaluation added 1.4 billion barrels of Discovered Petroleum-Initially-In-Place (PIIP as per the COGE Handbook definition) to Strata’s present resource base bringing it to a total of 3.4 billion barrels in place. Recent significant investment activity by large companies, our neighbors in the carbonate triangle, demonstrate clearly that the process of committing billions to the production of bitumen and other key infrastructure such as pipelines, is now gaining momentum quickly.

The "Technical Report Evaluation of Bitumen Resources Cadotte Central and West Leases” was prepared by Norwest Corporation, Mr. Geoff Jordan, Professional Geologist.

This report is designed to comply with the requirements of National Instrument 51-101 and the resource classification scheme and criteria elaborated in the current edition, Volume 1, of the Canadian Oil and Gas Evaluation Handbook. Elsewhere in this report the latter is referred to as the COGE Handbook.

These leases are referred to as Cadotte Central which was formerly referred to as the “Cadotte Target Area”, Cadotte West and Cadotte East. The Cadotte Central and Cadotte West areas are contiguous lease blocks that adjoin each other. Cadotte East is a group of three lease areas that are not contiguous and that do not adjoin the Cadotte Central and West areas. The resource estimates in the present report only apply to the contiguous leases of the Cadotte Central plus Cadotte West area. No bitumen evaluation has been made for Cadotte East as part of the present work.

The amount of exploration drilling and testing in the Cadotte Central area is sufficient for that part of the Peace River Oil Sand deposit to be classified as a Discovered Resource or Discovered Petroleum Initially in Place (PIIP). As the Cadotte West leases are not drilled, an estimate of the in-place resource is technically in the COGE classification of “Undiscovered.” However, it is the author’s opinion that there is sufficient evidence from the wells drilled in the surrounding areas for the judgment to be made that the bitumen bearing formations, the Bluesky, the Debolt and the Elkton, are all expected to be present on the Cadotte West leases. Hence, in this report, the in place bitumen resource on Cadotte West is considered to be Discovered PIIP and is classified as such. The classification of the Discovered PIIP into Low, Best and High categories was based on the following criteria:

	·	The Low Estimate includes all of the material that has a minimum grade of 8 wt% and a minimum thickness of 10 m. In order to identify the location of the highest grade ore, a second Low Estimate was also made. In this case the minimum grade was set at 10 wt% with the same minimum thickness of 10 m;

	·	The Best Estimate includes all of the material that has a minimum grade of 8 wt% but no minimum thickness; and

	·	The High Estimate includes all of the material without any grade or thickness constraint. Hence the latter is an estimate of the original bitumen in place for the zones under investigation.

A summary of the results of the estimates are presented on Table 1.1. This table shows the estimated PIIP for the Cadotte Central plus West leases.

TABLE 1.1

STRATA OIL & GAS

CADOTTE CENTRAL PLUS CADOTTE WEST

PETROLEUM INITIALLY IN PLACE (PIIP) MILLIONS OF BARRELS (MMSTB)

Formation	Low Estimate (10 wt% grade & 10 m thick. minimum)	Low Estimate (8 wt% grade & 10 m thick. minimum)	Most Likely Estimate (8 wt% grade minimum)	High Estimate
Bluesky/Gething	N/A	275	545	682
Debolt	1,436	2,100	2,157	2,534
Elkton	N/A	N/A	709	1,008
Total	1,436	2,375	3,411	4,225

These estimates of Discovered PIIP were used to prepare estimates of potentially recoverable bitumen. The estimate for Cadotte Central is shown on Table 1.2.

TABLE 1.2

STRATA OIL & GAS

CADOTTE CENTRAL PLUS CADOTTE WEST POTENTIALLY RECOVERABLE

BITUMEN- CADOTTE CENTRAL AREA MILLIONS OF BARRELS (MMSTB)

Formation	Low Estimate (10 wt% grade)	Low Estimate (8 wt% grade minimum)	Most Likely Estimate	High Estimate
Bluesky/Gething	N/A	N/A	N/A	39
Debolt	222	245	390	571
Elkton	N/A	N/A	127	245
Total	222	245	517	855

The estimates for recoverable bitumen, shown on Table 1.2, for the Cadotte Central Area are classified as contingent.

The estimate for Cadotte West is shown on Table 1.3.

TABLE 1.3

STRATA OIL & GAS

CADOTTE CENTRAL PLUS CADOTTE WEST POTENTIALLY RECOVERABLE

BITUMEN- CADOTTE WEST AREA MILLIONS OF BARRELS (MMSTB)

Formation	Low Estimate (10 wt% grade)	Low Estimate (8 wt% grade minimum)	Most Likely Estimate	High Estimate
Bluesky/Gething	N/A	47	142	22
Debolt	22	112	171	392
Elkton	N/A	N/A	57	138
Total	22	158	369	750

The estimates for Recoverable Bitumen, shown on Table 1.3, for the Cadotte West Area are classified as prospective. This classification for the recoverable bitumen is due to the lack of drill testing for this lease area.

Neither Strata nor Norwest make any express or implied warranties or guarantees of any kind concerning this report; including without limitation any implied warranty of merchantability or fitness for a particular purpose. Specifically, Norwest makes no warranty or guarantee that any property identified in this report will produce oil and/or gas in any quantity, or that any property identified in this report will produce or receive any economic, commercial or other benefit.

Readers of this 20-F are advised to read the May 10, 2013 report titled Technical Report Evaluation Of Bitumen Resources Cadotte Central and West Leases - Cadotte Leases, that is publicly available at www.sec.gov web site and was filed by the Company on May 29, 2013 under cover of 6-K.

Item 4A. Unresolved Staff Comments

Not applicable.

Item 5. Operating and Financial Review and Prospects

Management’s Discussion and Analysis of Financial Condition and Results of Operations

Management’s Discussion and Analysis of Financial Condition ("MD&A") and Results of Operations should be read in conjunction with the accompanying audited financial statements for the fiscal years ended December 31, 2014, 2013 and 2012. These reports are presented in United States dollars and have been prepared in accordance with accounting principles generally accepted in the United States, referred to in this Annual Report as US GAAP.

Certain statements contained in the MD&A and elsewhere in this Annual Report constitute forward-looking statements. Such forward-looking statements involve a number of known and unknown risks, uncertainties and other factors which may cause actual results, performance or achievements of the Company to be materially different from any future results, performance or achievements expressed or implied by such forward-looking statements. Readers are cautioned not to place undue reliance on these forward-looking statements which speak only as of the date the financial statements were made and readers are advised to consider such forward-looking statements in light of the risks set forth both below and prior in this report.

A. Operating Results

The following table sets forth a summary of our audited statement of operations for the fiscal years indicated:

	2014		2013		2012
Expenses	$	(753,287)	$	(574,609)	$	(241,995	)
Other income (expenses)		470,186		(2,223,559)		(1,614,795	)
Net income (loss)		(283,101)		(2,798,169)		(1,856,790	)
Earnings per share from continuing operations, basic and diluted	$	(0.00)	$	(0.04)	$	(0.03	)
Basic weighted average common shares outstanding (in millions)		87.2		80.1		71.3
Diluted weighted average common shares outstanding (in millions)		N/A		N/A		N/A

Year ended December 31, 2014 compared to the year ended December 31, 2013

RESULTS OF OPERATIONS

In 2014 the Company focused its efforts on further exploration and permitting for drilling on its Cadotte West leases. Resources were deployed to follow up and move forward with the development potential of our leases by engaging third party service providers to provide additional technical information and the necessary data to assist with the Oil Sands Exploration (OSE) application process. The Company moved forward on planned initiatives as follows:

Completed a seismic study to evaluate the Cadotte West property for heavy-oil recovery using cold production.

Commenced initial planning and permitting activities needed to develop a drill program and continue exploration of the identified targets for the Cadotte West property.

The Company engaged specialized third party service provider(s) to assist with the development of a drill program which includes the submission of an Oil Sands Exploration plan, the (OSE) to the Crown. Elements of an OSE application include, but are not limited to, mapping and locating services, sensitive areas, wildlife zones, historical work in the area, site access, environmental services, exploration operations detail, stake holders and First Nation consultation and project management services. The OSE program approval was received in February 2015 granting the Company two years from the date of issue to conduct its exploration program.

During the year ended December 31, 2014, the Company had a net loss of $283,101 compared to a net loss from operations of $2,798,169 for the year ended December 31, 2013, a decrease in net loss of $2,515,068. Not including the non-cash changes in fair value derivative liability gain of $466,499 (2013 – loss of $2,216,119), expenses for the period increased $178,678 to $753,287 for the year ended December 31, 2014 from $574,609 in 2013 primarily due to an increase in consulting fees of $135,681 related to stock options issued to consultants. Consulting fees include $421,923 in stock compensation expense due to the grant of an aggregate 3,770,000 options which were issued to consultants to provide further incentive to perform and contribute to the long-term growth of the Company. Net of the non-cash consulting fees from the grant of stock options, expenses decreased $243,246. The Company also experienced an increase in professional fees of $39,034 related to the Company’s work towards becoming a reporting issuer in Canada and an increase in office and sundry expenses of $6,051, which was the result of additional office and travel expenses related to the Company’s oil sands exploration efforts.

For the year ended December 31, 2014, the Company recorded a gain on the change in fair value of derivative liability of $466,499 (2013 – loss $2,216,119). This item is a non-cash item and was recorded in accordance with ASC 815. This guidance requires entities to evaluate whether an equity-linked financial instrument (or embedded feature) is indexed to its own stock by assessing the instrument’s contingent exercise provisions and settlement provisions. Instruments not indexed to their own stock fail to meet the scope exception of Accounting for Derivative Instruments and Hedging Activities, ASC 815-10-15-74(a), and should be classified as a liability and marked-to-market. The Company has issued freestanding warrants that are accounted for as derivative instrument liabilities because they are exercisable in a currency other than the functional currency of the Company and thus do not meet the “fixed-for-fixed” criteria of ASC 815-40-15. The warrants are exercisable in United States dollars and the Company’s functional currency is the Canadian dollar.

REVENUES

The Company did not earn any revenue for the year ended December 31, 2014 or 2013. We do not anticipate earning revenues until such time as we have entered into commercial production of our oil and gas properties. We can provide no assurance that we will discover commercially exploitable levels of oil or gas resources on our properties, or if such resources are discovered, that we will enter into commercial production of our oil and gas properties.

LOSS FROM OPERATIONS

The Company recognized a loss from operations of $283,101 for the year ended December 31, 2014 compared to a loss from continuing operations in 2013 of $2,798,169, a decrease in net loss of $2,515,068. Excluding the non-cash change in derivative liability, expenses for 2014 increased primarily due to stock options expense for options issued to consultants during the year.

INTEREST AND OTHER INCOME (EXPENSE)

Included in other income (expense) is a gain of $466,499 relating to the change in fair value of derivative liability resulting from a decrease in the fair value of the derivative liability and the exercise of outstanding warrants, as at December 31, 2014 compared to December 31, 2013. The decrease in derivative liability was the result of a decrease in the Company’s stock price at December 31, 2014 compared to 2013. See Note 5 of the Financial Statements for more on the change in the derivative liability. The Company recorded a loss on the change in the derivative liability in the amount of $2,216,119 at December 31, 2013. The Company determined the fair value of the derivative liability to be $4,482,926 as of December 31, 2014 based on an acceptable valuation model.

Year ended December 31, 2013 compared to the year ended December 31, 2012

RESULTS OF OPERATIONS

During the year ended December 31, 2013, the Company had a net loss of $2,798,169 compared to a net loss of $1,856,790 for the year ended December 31, 2012, an increase of $941,379. Not including the non-cash changes in fair value derivative liability loss of $2,216,119 (2012 – loss of $1,620,319), expenses for the period increased $332,614 to $574,609 for the year ended December 31, 2013 from $241,995 in 2012 primarily due to an increase in consulting fees of $327,539 associated with property assessment and maintaining a strategic presence within the local oil and gas industry. Consulting fees also include $80,808 related to stock compensation expense for the year ended December 31, 2013.

For the year ended December 31, 2013, the Company recorded a loss for a change in fair value of derivative liability of $2,216,119 (2012 – loss $1,620,319). This item is a non-cash item and was recorded in accordance with ASC 815. This guidance requires entities to evaluate whether an equity-linked financial instrument (or embedded feature) is indexed to its own stock by assessing the instrument’s contingent exercise provisions and settlement provisions. Instruments not indexed to their own stock fail to meet the scope exception of Accounting for Derivative Instruments and Hedging Activities, ASC 815-10-15-74(a), and should be classified as a liability and marked-to-market.

REVENUES

The Company did not earn any revenue for the year ended December 31, 2013 or 2012. We do not anticipate earning revenues until such time as we have entered into commercial production of our oil and gas properties. We are presently in the exploration stage of our business and we can provide no assurance that we will discover commercially exploitable levels of oil or gas resources on our properties, or if such resources are discovered, that we will enter into commercial production of our oil and gas properties.

CONTINUING OPERATIONS

The Company recognized a loss from operations of $2,798,169 for the year ended December 31, 2013 compared to a loss from operations in 2012 of $1,856,790, an increase of $941,379. Excluding the non-cash change in derivative liability, expenses for 2013 increased significantly due to increased activity associated with property assessment and maintaining a strategic presence within the local oil and gas industry.

INTEREST AND OTHER INCOME (EXPENSE)

Included in other income (expense) is a loss of $2,216,119 relating to the change in fair value of derivative liability resulting from an increase in the fair value of the derivative liability, as at December 31, 2013 compared to December 31, 2012. The increase in derivative liability was the result of an increase in outstanding warrants issued during the year along with a significant increase in the Company’s stock price at December 31, 2013 compared to 2012. See Note 5 of the Financial Statements for more on the change in the derivative liability. The Company recorded a loss on the change in the derivative liability in the amount of $1,620,319 at December 31, 2012. The Company determined the fair value of the derivative liability to be $5,178,906 as of December 31, 2013 based on an acceptable valuation model.

B. Liquidity and Capital Resources

(in U.S. dollars)	As at December 31,
	2014		2013			2012
Cash and cash equivalents	$	118,873	$	440,612		$	134,125
Working capital (deficit)		(4,268,555)		(4,667,621	)		(2,238,071	)

Net cash provided by (used in)
Operating activities		(247,614)		(524,549	)		(190,894	)
Investing activities		(425,989)		(179,357	)		(121,003	)
Financing activities		371,200		1,007,002			226,400

As of December 31, 2014, we had $118,873 in cash, a decrease of $321,739 from December 31, 2013. The decreased cash balance is primarily due to capitalized expenditures related to evaluating and exploring the Company’s oil and gas properties and general operating expenses associated with the preparation of an OSE application, along with evaluation of additional resources properties. Management estimates that the Company will require approximately $1,525,000 to fund planned operations for the next twelve months. Therefore, current cash on hand is not sufficient to fund planned operations for 2015. Our policy is to pay all operational expenses when due, provided that the vendor, in the normal course of business, has satisfied all necessary conditions for payment.

We have no long-term debt. In 2015 our most significant capital requirement is expected to be associated with the commencement of our drill program and recent “OSE”. We cannot proceed with our drill program until we secure adequate funding to initiate the program, which, we have estimated $1,000,000 as an initial baseline for this purpose. Going forward we expect the short and long term funding of our oil and gas operations to be financed primarily through equity issuance in the form of private placements and the exercise of warrants. In addition we continue to work with potential partners to discuss funding arrangements which would facilitate furtherance of our property interests. We believe that our available cash may not be sufficient to fund our working capital requirements to maintain, explore and develop our property interests for the next twelve months. We cannot be certain that any required additional financing will be available on terms favorable to us as the risky nature of this enterprise and lack of tangible assets places debt financing beyond the credit-worthiness required by most banks or typical investors of corporate debt until such time as the economic viability of our oil sands properties can be demonstrated. If additional funds are raised by the issuance of our equity securities, existing stockholders will experience dilution of their ownership interest. If adequate funds are not available or not available on acceptable terms, we may be unable to continue, fund expansion, pursue further development nor respond to competitive pressures.

Net cash used in operating activities during the twelve months ended December 31, 2014 was $247,614 compared to $525,549 in 2013. The decrease in cash used in operating activities was primarily due to an increase in non-cash stock compensation associated with consulting fees of $421,923 along with increases in accounts payable of $47,396 and accrued liabilities of $32,387.

Cash used in investing activities for 2014 was $425,989 compared to cash used in investing of $179,357 in 2013. The Company spent $23,892 on deposits to the Alberta Energy trust compared with $6,152 in the prior year. The Company also spent $78,882 on payments to the Province of Alberta to maintain the Company’s property leases, compared to $69,651 in 2013. Capitalized exploration and evaluation expenditures on the Company’s oil and gas properties totaled $219,904 compared to $37,740 in 2013. The Company also spent $106,946 on advances under notes receivable, to related parties in 2014 compared with advances of $65,814 in 2013.

The Company generated cash inflows from financing activities of $371,200 compared to $1,007,002 in 2013. The Company raised $301,600 in funds from a series of private placements executed during 2014 and $69,600 in proceeds from the exercise of warrants. In 2013 the Company raised $969,502 in proceeds from private placements completed during the year and $37,500 in proceeds from the exercise of warrants. See Note 9 to the financial statements for more information.

We had cash of $118,873 as of December 31, 2014. We anticipate that we will incur the following expenditures through the end of our next fiscal year:

	·	$200,000 in connection with property lease payments and follow up analysis on the Company’s oil sands properties;

	·	$325,000 for operating expenses, including working capital, consulting fees, general and administrative, professional, legal and accounting expenses;

	·	$1,000,000 as a base line to commence a drill program and exploit some of the drill targets identified in the OSE.

We are an exploration stage company, with limited operating history, which raises substantial doubt as to our ability to successfully develop profitable business operations and makes an investment in our common shares very risky.

We have only recently commenced oil and gas exploration operations. Our prospects must be considered in light of the risks, expenses and difficulties frequently encountered in establishing a business in the oil and natural gas industries. We have yet to generate any revenues from operations. There is nothing at this time on which to base an assumption that our business operations will prove to be successful or that we will ever be able to operate profitably. Our future operating results will depend on many factors, including:

	·	our ability to raise adequate working capital;

	·	success of our exploration and development;

	·	demand for natural gas and oil;

	·	the level of our competition;

	·	our ability to attract and maintain key management and employees; and

	·	our ability to efficiently explore, develop and produce sufficient quantities of marketable natural gas or oil in a highly competitive and speculative environment while maintaining quality and controlling costs.

If capital is not available to fund future operations, we will not be able to pursue our business plan and operations would come to a halt and our common shares would be nearly worthless.

Cash on hand is not sufficient to fund our anticipated operating needs for the next twelve months. We will require substantial additional capital to participate in the development of our properties which have not had any production of oil or natural gas as well as for acquisition and/or development of other producing properties. Because we currently do not have any cash flow from operations we need to raise additional capital, which may be in the form of loans from current shareholders and/or from private equity offerings. Our ability to access capital will depend on our success in participating in properties that are successful in exploring for and producing oil and gas at profitable prices. It will also be dependent upon the status of the capital markets at the time such capital is sought. Should sufficient capital not be available, the development of our business plan could be delayed and, accordingly, the implementation of our business strategy would be adversely affected. In such event it would not be likely that investors would obtain a profitable return on their investments or a return of their investments at all.

Volatility of oil and gas prices and markets could make it more difficult for us to achieve profitability and less likely for investors in our common shares to receive a return on their investment.

	·	worldwide or regional demand for energy, which is affected by economic conditions

	·	the domestic and foreign supply of natural gas and oil

	·	weather conditions


	·	domestic and foreign governmental regulations

	·	political conditions in natural gas and oil producing regions

	·	the ability of members of the Organization of Petroleum Exporting Countries to agree upon and maintain oil prices and production levels

	·	the price and availability of other fuels

The potential profitability of oil and gas ventures depends upon factors beyond our control.

Critical Accounting Estimates:

The preparation of the Company's financial statements requires management to make estimates and assumptions regarding future events. These estimates and assumptions affect the reported amounts of certain assets and liabilities and disclosure of contingent liabilities.

The Company follows the full cost method of accounting for natural gas and oil operations. Under the full cost method, all costs incurred in the acquisition, exploration and development of natural gas and oil reserves are initially capitalized into cost centers on a country-by-country basis. The Company’s current cost centers are located in Canada. Such costs include land acquisition costs, geological and geophysical expenditures, carrying charges on non-producing properties, costs of drilling and overhead charges directly related to acquisition, exploration and development activities.

Costs capitalized, together with the costs of production equipment, are depleted and amortized on the unit-of-production method based upon the estimated net proved reserves, as determined by independent petroleum engineers. The percentage of total reserve volumes produced during the year is multiplied by the net capitalized investment plus future estimated development costs in those reserves. Costs of acquiring and evaluating unproved properties are initially excluded from depletion calculations. These unevaluated properties are assessed periodically to ascertain whether an impairment has occurred. When proved reserves are assigned or the property is considered to be impaired, the cost of the property or the amount of the impairment is added to costs subject to depletion calculations.

Under full cost accounting rules, capitalized costs, less accumulated amortization and related deferred income taxes shall not exceed an amount (the ceiling) equal to the sum of: (i) the after tax present value of estimated future net revenues computed by applying current prices of oil and gas reserves to estimated future production of proved oil and gas reserves as of the date of the latest balance sheet presented, less estimated future expenditures (based on currents costs) to be incurred in developing and producing the proved reserves computed using a discount factor of ten percent and assuming continuation of existing economic conditions; (ii) the cost of properties not being amortized; and (iii) the lower of cost or estimated fair value of unproven properties included in the costs being amortized. If unamortized costs capitalized within a cost center, less related deferred income taxes, exceed the ceiling, the excess shall be charged to expense and separately disclosed during the period in which the excess occurs. Amounts required to be written off shall not be reinstated for any subsequent increase in the cost center ceiling.

Estimates of undiscounted future cash flows that we use for conducting impairment tests are subject to significant judgment decisions based on assumptions of highly uncertain future factors, such as crude oil and natural gas prices, production quantities, estimates of recoverable reserves, and production and transportation costs. Given the significant assumptions required and the strong possibility that actual future factors will differ, we consider the impairment test to be a critical accounting procedure.

In accordance with ASC 410, Asset Retirement and Environmental Obligations, the fair value of an asset retirement cost, and corresponding liability, should be recorded as part of the cost of the related long-lived asset and subsequently allocated to expense using a systematic and rational method. The Company has recorded an asset retirement obligation at December 31, 2014 and 2013 (Note 7) to reflect its legal obligations related to future abandonment of its oil and gas interests using estimated expected cash flow associated with the obligation and discounting the amount using a credit-adjusted, risk-free interest rate. At least annually, the Company will reassess the obligation to determine whether a change in any estimated obligation is necessary. The Company will evaluate whether there are indicators that suggest the estimated cash flows underlying the obligation have materially changed. Should those indicators suggest the estimated obligation has materially changed the Company will accordingly update its assessment.

Management has made significant assumptions and estimates determining the fair market value of stock-based compensation granted to employees and non-employees. These estimates have an effect on the stock-based compensation expense recognized and the contributed surplus and share capital balances on the Company’s Balance Sheet. The value of each option award is estimated on the date of grant using the Black-Scholes option-pricing model. To date, all of our stock option grants have been to non-employees. Increases in our share price will likely result in increased stock option compensation expense. The Black-Scholes option-pricing model requires the input of subjective assumptions, including the expected term of the option award and stock price volatility. The expected term of options granted for the purposes of the Black-Scholes calculation is the term of the award since all grants are to non-employees. These estimates involve inherent uncertainties and the application of management judgment. An expected forfeiture rate of Nil was used in the recognition of compensation expense for those options not yet vested at December 31, 2014.

These accounting policies are applied consistently for all years presented. Our operating results would be affected if other alternatives were used. Information about the impact on our operating results is included in the notes to our financial statements.

Valuation of Derivative Instruments

US GAAP requires that embedded derivative instruments be bifurcated and assessed, along with free-standing derivative instruments such as warrants and stock-options to determine whether they should be considered a derivative liability and subject to re-measurement at their fair value. Warrants with such provisions will no longer be recorded to equity. The Company has issued freestanding warrants that are accounted for as derivative instrument liabilities because they are exercisable in a currency other than the functional currency of the Company and thus do not meet the “fixed-for-fixed” criteria of ASC 815-40-15. The warrants are exercisable in United States dollars and the Company’s functional currency is the Canadian dollar. In estimating the appropriate fair value, the Company uses a Black-Scholes option pricing model.

Inflation

We operate in Canada only, where inflation for our operational costs is at low levels (i.e. in the 2%-5% range).

Impact of Foreign Currency Fluctuations

Primarily we hold our cash reserves in Canadian dollars. We incur the majority of our expenses and capital expenditures in Canadian dollars, however; we do have US transactions and therefore, an increase or decrease in the value of the Canadian dollar versus the U.S. dollar would have an effect on us. The Company also translates its financial statements from Canadian dollars to U.S. dollars for financial reporting purposes. Changes in the in the value of the Canadian dollar versus the U.S. dollar will have a direct impact on the financial information reported by the Company.

Government Policies

We are subject to regulations of the Government of Canada and the Government of Alberta. Such regulations may relate directly and indirectly to our operations including production, marketing and sale of hydrocarbons, royalties, taxation, environmental matters and other factors. There is no assurance that the laws relating to our operations will not change in a manner that may materially and adversely affect us, however, there has been no material impact on us from changes in such laws in the past three fiscal periods.

C. Research and development, patents and licenses, etc.

See Item 4.B. “Business Overview”.

D. Trends Information

There are no known trends other than those previously disclosed in this report.

E. Off-Balance Sheet Arrangements

We do not have any off balance sheet arrangements as of December 31, 2014 and December 31, 2013 or as of the date of this report.

F. Tabular Disclosure of Contractual Obligations

The following table outlines contractual obligations at December 31, 2014.

Contractual Obligations

Payments due by period

Total

Less than 1 year

1-3 years

4-5 years

More than five years

Annual Oil Sands Lease Payments:

Drowned property lease

1,545

–

Peace River property leases

400,846

63,332

126,664

84,186

Capital (Finance) Lease Obligations

–

Operating Lease Obligations

–

Purchase Obligations

–

Other Long-Term Liabilities Reflected on the Company’s Balance Sheet Under the GAAP of the primary financial statements

–

Total

402,391

64,877

126,664

84,186

The Drowned Property is comprised of a single lease with the government of the Province of Alberta, Canada requiring annual lease payments of USD $1,545 (CDN $1,792). The lease is a fifteen-year lease and expires on October 4, 2015.

The Peace River Project is currently comprised of 17 leases with the government of the Province of Alberta, Canada requiring annual lease payments of USD $63,332 (CDN $73,742). The leases are fifteen-year leases that expire beginning June 15, 2020 through January 20, 2022.

At December 31, 2014, the Company had trade payables and accrued liabilities of $81,309. All of these obligations are due in less than one year.

At December 31, 2014, the Company had a derivative liability of $4,482,926 that relates to warrants with an exercise price in a different currency than the Company’s functional currency (see Note 5 in the financial statements).

G. Safe Harbor

This Annual Report contains forward-looking information. Forward-looking information includes statements relating to future actions, prospective products, future performance or results of current or anticipated products, sales and marketing efforts, costs and expenses, interest rates, outcome of contingencies, financial condition, results of operations, liquidity, business strategies, cost savings, objectives of management of the Company and other matters. Forward-looking information may be included in this Annual Report or may be incorporated by reference from other documents filed with the SEC by the Company. One can find many of these statements by looking for words including, for example, “believes,” “expects,” “anticipates,” “estimates” or similar expressions in this Annual Report or in documents incorporated by reference in this Annual Report. The Company undertakes no obligation to publicly update or revise any forward-looking statements, whether as a result of new information or future events.

The Company has based the forward-looking statements relating to the Company’s operations on management’s current expectations, estimates and projections about the Company and the industry in which it operates. These statements are not guarantees of future performance and involve risks, uncertainties and assumptions that we cannot predict. In particular, we have based many of these forward-looking statements on assumptions about future events that may prove to be inaccurate. Accordingly, the Company’s actual results may differ materially from those contemplated by these forward-looking statements. Any differences could result from a variety of factors including, but not limited to, general economic and business conditions, competition, and other factors, including those described in Item 3.D. “Risk Factors.”

Recent Accounting Pronouncements:

ASU No. 2014-10

One June 10, 2014, the FASB issued Accounting Standards Update No. 2014-10 (ASU 2014-10), Development Stage Entities (Topic 915)” Elimination of Certain Financial Reporting Requirements, Including an Amendment to Variable Interest Entities Guidance in Topic 810, Consolidation, which removes all incremental financial reporting requirements from GAAP for development stage entities, including the removal of Topic 915 from the FASB Accounting Standards Codification. The presentation and disclosure requirements in Topic 915 will no longer be required for the first annual period beginning after December 15, 2014. The revised consolidation standards are effective as of May 31, 2014 and early adoption is permitted. The Company has elected to early adopt ASU 2014-10 and as a result the Company has revised its statements of operations, cash flows and equity to exclude reporting for the period from date of inception through December 31, 2014.

ASU No. 2014-09

In May 2014, the FASB issued ASU 2014-09, “Revenue from Contracts with Customers (Topic 606)” (“ASU 2014-09”). ASU 2014-09 is intended to improve the financial reporting requirements for revenue from contracts with customers by providing a principle based approach. The core principle of the standard is that revenue should be recognized when the transfer of promised goods or services is made in an amount that the entity expects to be entitled to in exchange for the transfer of goods and services. ASU 2014-09 also requires disclosures enabling users of financial statements to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. This standard will be effective for financial statements issued by public companies for annual reporting periods beginning after December 15, 2016. Early adoption is not permitted. The Company is currently evaluating the potential impact of ASU 2014-09 on the financial statements.

Item 6. Directors, Senior Management and Employees

A. Directors and Senior Management

The directors, officers and other employees upon whose work the Company is dependent are as follows:

Name	Position	Position Held Since
Trevor Newton (1)	Chairman of the Board, Director	May 22, 2014
Ron Daems	President, Chief Executive Officer, Secretary, Director	July 19, 2010
Michael Ranger	Director	July 11, 2012

(1)	Mr. Newton was appointed as Chairman of the Board on May 22, 2014.

Our Directors hold office until the next annual meeting of our shareholders or until their successors are duly elected and qualified. Shareholders elect Directors by vote in proxy or in person. None of our Directors have any family relationships with any of our other Directors or Executive Officers. Our Directors do not exercise independent supervision over management as there are no independent management positions. Set forth below is a summary description of the principal occupation and business experience of each of our Directors and Executive Officer for at least the last five years.

TREVOR NEWTON is the founder of Strata Oil & Gas, and has been involved in the development of the company from the initial land acquisition and discovery stage, through to the present. He has assisted the company by establishing its corporate focus, assembling its team, and helping advance its core project. Mr. Newton's corporate experience has primarily been in the resource sector, where he has assisted private and public companies in their financing, project acquisition, and development. Mr. Newton has a B.Sc. in Economics from the University of Victoria and an M.A. in Economics from Simon Fraser University.

RON DAEMS brings extensive financial and resource industry experience to Strata Oil & Gas Inc. In the span of his career, he has focused primarily on business development, strategic planning and financial analysis, while serving as project manager for numerous capital ventures. From 2000 through 2003, Mr. Daems was a portfolio manager of a multinational investment firm. In 2004, Mr. Daems founded and became the CEO of Emerging Business Solutions Inc., a privately held business development company focused primarily on assisting startup companies in the resource sector to develop their land acquisition strategies and their operational and administrative systems. Since January 2007, Mr. Daems has also served as President and CEO of Capex Energy Services Inc., a privately held company.

MICHAEL RANGER is an experienced petroleum consultant with a prolific career providing services to an array of the world's largest oil companies. He has extensive oil sands & heavy oil evaluation and research experience in reservoir characterization, sedimentology and sequence stratigraphy of Athabasca, Wabasca, Cold Lake, Peace River and international oil sands regions. He has conducted and supervised numerous resource evaluation projects integrating core, outcrop and wireline logs. Recent major contracts include: Suncor Energy, Ross Smith Energy Group, Hatch Engineering, Golder Associates, Laracina Energy, Nexen, Statoil, Murphy Oil, Husky Oil, Brion Energy, Athabasca Oil Corp, Oilsands Quest, DMT Geoscience, ARC Resources, Marathon, Paramount Energy, Kennecott Canada, Total Canada, OPTI Canada, Koch Canada, Quadrise.

Dr. Ranger is currently an independent petroleum consultant and is a director of Canadex Resources Ltd. Prior to this, he served on the Scientific Advisory Board of Gushor Inc. from 2007 to 2009, and as a senior geologist at Gulf Canada Resources between 1977 and 1985. Dr. Ranger has a Ph.D. in Petroleum Geology from the University of Alberta, a MSc. Degree in Sedimentary Geology from Memorial University of Newfoundland, and a BSc. Geology from Concordia University. His professional affiliations include the American Association of Petroleum Geologists, Canadian Society of Petroleum Geologists and the Canadian Well Logging Society.

B. Compensation

The following table shows compensation paid to the Company’s executives for the fiscal year ended December 31, 2014:

Name

Title

Year

Salary

Bonus

Stock
Options
Granted

Other
Annual
Compensation

Restricted
Stock
Awarded

LTIP
Payouts
($)

All Other
Compensation

Trevor Newton(1)

Director - Chairman

2014

–

2,000,000

–

Ron Daems (2)

Director, President, CEO, Secretary

2013

–

500,000

–

$45,032

Michael Ranger

Director

2013

–

(1)	Trevor Newton was appointed Chairman of the Board of Directors on May 22, 2014.
(2)	Ron Daems was appointed President, Chief Executive Officer, Secretary and Director on July 19, 2010. Mr. Daems does not bill the Company for these services, however, he does have a service agreement with the Company to assist with the identification, acquisition and service of certain exploration style properties that fit the parameters of the Company’s business plan.

Change of Control Remuneration.

The Company had no plans or arrangements with respect to remuneration received, or that may be received by executive officers of the Company in 2014, to compensate such officers in the event of termination of employment (as a result of resignation, retirement, change of control) or a change of responsibilities following a change of control.

6.C. Board Practices

6.C.1. Terms of Office.

Refer to Item 6.A.1.

6.C.2. Directors’ Service Contracts.

Mr. Newton, Chairman of the Board, does not have a service agreement with the Company for his services.

Mr. Daems, President, CEO, Secretary and Director, supervises the company's operations. Mr. Daems does not bill the Company for these services, however he does have a service agreement with the Company to assist with the identification, acquisition and service of certain exploration style properties that fit the parameters of the Company’s business plan. The Company recognized $45,032 as consulting fees for the year ended December 31, 2014 under the agreement. The agreement did not provide for termination benefits of any kind.

Dr. Ranger, Director, has a service agreement with the Company for his Director services. The agreement does not provide for termination benefits of any kind.

6.C.3. Board of Director Committees.

The Audit Committee oversees the accounting and financial reporting processes of the Company and all audits and external reviews of the financial statements of the Company on behalf of the Board, and has general responsibility for oversight of internal controls, accounting and auditing activities of the Company. The Committee reviews, on a continuous basis, any reports prepared by the Company's external auditors relating to the Company's accounting policies and procedures, as well as internal control procedures and systems. The Committee is also responsible for examining all financial information, including annual financial statements, prepared for securities commissions and similar regulatory bodies prior to filing or delivery of the same. The Audit Committee also oversees any complaints and concerns regarding accounting, internal controls or auditing matters and the resolution of issues identified by the Company's external auditors. The Audit Committee recommends to the Board the firm of independent auditors to be nominated for appointment by the shareholders and the compensation of the auditors. The Audit Committee meets on an as needed basis. Currently the Board of Directors functions as the audit committee.

6.D. Employees

The Company utilizes third party consultants and had no full-time employees on December 31, 2014 or during the 2013 fiscal year. It is anticipated that we will need to add managerial, technical and administrative staff in the future in order to realize our business objectives. We currently outsource to outside engineers, geologists and other third party consultants on an as-needed basis.

6.E. Share Ownership

The table below indicates as of April 2, 2015 the ownership of outstanding shares of the Company held by each of our officers and directors. Information relating to ownership of common shares by officers and directors is based upon information furnished by each person.

Beneficial Owner	Shares		Percent of total issued % (1)		Options

All Executive Officers and Directors as a Group		16,710,746		18.36%		3,300,000
Trevor Newton(2)		16,669,746		18.28%		2,000,000
Ron Daems(3)		41,000		.05%		500,000
Michael Ranger(4)		–		–		800,000

(1)	Based on 91,194,183 shares of common stock issued and outstanding as of April 2, 2015.
(2)	Mr. Newton was awarded 2,000,000 stock options to purchase common shares of the Company at an exercise price of $.14 on July 1, 2014 and are fully vested.
(3)	Mr. Daems was awarded 500,000 stock options to purchase common shares of the Company at an exercise price of $.14 on July 1, 2014 and are fully vested.
(4)	Dr. Michael Ranger was awarded 200,000, 200,000, 200,000 and 200,000 stock options to purchase common shares of the Company at an exercise price of $2.285, $0.61, $0.07 and $0.14 on July 21, 2006, March 19, 2008, July 11, 2012 and July 11, 2012, all which are fully vested.

The persons named in this table, based upon the information they have provided to us, have sole voting and investment power with respect to all shares of common stock owned by them.

Item 7. Major Shareholders and Related Party Transactions

7.A. Major Shareholders

7.A.1.a. Holdings By Major Shareholders.

The table below indicates the share ownership as of April 2, 2015 of any person or entity that management believes is the beneficial owner of more than 5% of our outstanding common shares.

Major Shareholders		Number of Shares				Beneficial Ownership (%)
T. Newton			16,669,746				18.28

7.A.1.b. Significant Changes in Major Shareholders’ Holdings.

Trevor Newton’s percentage ownership increased by 11.69%.

7.A.1.c. Different Voting Rights.

The Company’s major shareholders do not have different voting rights.

7.A.2 Share Ownership.

On April 2, 2015, the Company had one hundred eighty-one (181) registered shareholders holding 91,194,183 shares. Of these, one hundred thirty eight (138) registered shareholders holding 11,767,786 common shares have addresses in the United States.

7.A.3 Ownership or Control of the Company.

The Company is not, directly or indirectly, owned or controlled by another corporation, foreign government or natural or legal person, severally or jointly.

7.A.4. Change of Control of Company Arrangements.

There is no arrangement known to the Company which may, at a subsequent date, result in a change in control of the Company.

7.B. Related Party Transactions

The Company has entered into short term note agreements for business purposes with two (2) related parties wherein the Company retains the right to enter into an option agreement with the borrower for development rights on the borrowers' oil sands leases in Alberta. Refer to Note 4 – Notes Receivable Related Parties and Note 8 - Related Party Transactions.

7.C. Interests of Experts and Counsel

Not applicable.

Item 8. Financial Information

A. Financial Statements and Other Financial Information

The Company's financial statements are stated in United States Dollars and are prepared in accordance with U.S. Generally Accepted Accounting Principles (GAAP).

The financial statements, as required under Item 18, are included in that item. The audit report of Peterson Sullivan LLP is included herein immediately preceding the financial statements.

Audited Financial Statements:

Fiscal years ended December 31, 2014 and 2013.

8.A.7. Legal/Arbitration Proceedings

The Company is not involved in any legal proceedings which subject it to any contingent liabilities.

8.A.8. Policy on Dividend Distributions

We have never declared or paid any cash dividends on our common shares nor do we anticipate paying any in the foreseeable future. Furthermore, we expect to retain any future earnings to finance our operations and expansion. The payment of cash dividends in the future will be at the discretion of our Board of Directors and will depend upon our earnings level, capital requirements, any restrictive loan covenants and other factors the Board considers relevant.

B. Significant Changes

Not Applicable

Item 9. The Offer and Listing

A. Offer and Listing Details

The following tables set forth the price history of the Company’s stock.

1.	Annual high and low market prices for the last five full financial years:

Year	Market Price
	High Price	Low Price
2014	$0.35	$0.11
2013	$0.31	$0.11
2012	$0.15	$0.05
2011	$0.38	$0.08
2010	$0.52	$0.01

2.	High and low market prices for each full financial quarter during the two most recent full financial years:

Financial Quarter		Market Price
Year	Quarter	High Price	Low Price
2014	Fourth Quarter of 2014	$0.26	$0.11
	Third Quarter of 2014	$0.35	$0.14
	Second Quarter of 2014	$0.18	$0.13
	First Quarter of 2014	$0.20	$0.12

2013	Fourth Quarter of 2013	$0.27	$0.17
	Third Quarter of 2013	$0.31	$0.11
	Second Quarter of 2013	$0.14	$0.11
	First Quarter of 2013	$0.18	$0.11

3.	High and low market prices for each of the six most recent months:

Month	Market Price
	High Price	Low Price
October 2014	$0.26	$0.17
November 2014	0.18	0.12
December 2014	0.17	0.11
January 2015	0.15	0.11
February 2015	0.11	0.09
March 2015	0.13	0.08

B. Plan of Distribution.

Not applicable.

C. Markets.

The Company’s common stock trades over the counter in the United States on the OTCQB tier of the electronic over-the-counter marketplace operated by OTC Markets Group, Inc. under the symbol SOIGF.

D. Selling Shareholders.

Not applicable.

E. Dilution.

Not applicable.

F. Expenses of the Issue.

Not applicable.

Item 10. Additional Information

A. Share Capital.

Not applicable.

B. Memorandum and Articles of Association

Corporate Registration

Strata Oil & Gas Inc. was originally incorporated under the laws of the State of Nevada on November 18, 1998 and commenced operations in January 1999. The Company filed Articles of Continuance under the Canada Business Corporations Act on August 20, 2004 and is registered with Industry Canada under Corporation No. 425346-9.

Objects and Purposes

Strata’s Articles of Continuance do not specify any specific objects or purposes. Under the Canada Business Corporations Act, a corporation has all the legal powers of a natural person. Corporations may not undertake certain limited business activities such as operating as a trust company or railroad without alterations to its form of articles and specific government consent.

Powers of Directors

Under the Company's Articles and Bylaws, the Board of Directors has the authority, without further action by the holders of the outstanding Common Shares, to issue preferred shares from time to time in one or more series, to fix the number of shares constituting any series, and to fix the terms of any such series, including dividend rights, dividend rates, conversion or exchange rights, voting rights, rights and terms of redemption (including sinking fund provisions), the redemption price and the liquidation preference or such series.

The Company’s Articles and Bylaws provide that the Board of Directors may, from time to time, with or without the authority or the authorization of the shareholders, in such amounts and on such terms as it deems expedient, cause the Company to:

(a) borrow money upon the credit of the Company, including by way of overdraft;

(b) issue, re-issue, sell or pledge bonds, debentures, notes or other evidences of indebtedness of the Company, whether secured or unsecured;

(d) charge, mortgage, hypothecate, pledge or otherwise create a security interest in the undertaking of the Company or in all or any of the currently owned or subsequently acquired property and assets of the Company, including without limiting the generality of the foregoing, real and personal property, movable and immovable property, tangible and intangible assets, book debts, rights, powers and franchise, to secure any present or future obligation of the Company.

The Board may from time to time delegate to a committee, to a Director or to an Officer of the Company all or any of the powers conferred on the Board by law or the Bylaws to such extent and in such manner as the Board from time to time determines.

There are no age limit requirements pertaining to the retirement or non-retirement of directors and a director need not be a shareholder of the Company.

The Company does not have any compensation agreements with the Board of Directors, however the Company may reimburse each director for the reasonable expenses that he or she may incur in or about the business of the Company. If any director performs any professional or other services for the Company that in the opinion of the directors is outside the ordinary duties of a director, or if any director is otherwise specially occupied in or about the Company’s business, he or she may be paid either in addition to or substitution for any other remuneration they may be entitled to receive.

The Company's Bylaws require the Company to indemnify all directors and officers of the Company, a former director or officer of the Company or any other individual who acts or acted at the Company's request as a director or officer, or an individual acting in a similar capacity.

Description of Securities

The Company is authorized to issue an unlimited number of shares of common stock (the “Common Shares”) as well as an unlimited number of shares of preferred stock (the “Preferred Shares”).

Subject to the rights of holders of Preferred Shares in the future, if any, holders of the Common Shares are entitled to share equally on a per share basis in such dividends as may be declared by the Board of Directors out of funds legally available therefore. There are presently no plans to pay dividends with respect to the Common Shares. Upon the Company’s liquidation, dissolution or winding up, after payment of creditors and the holders of any of the Preferred Shares, if any, the Company’s assets will be divided pro rata on a per share basis among the holders of the Common Shares. The Common Shares are not subject to any liability for further assessments. There are no conversions or redemption privileges nor any sinking fund provisions with respect to the Common Shares and the Common Shares are not subject to call. The holders of Common Shares do not have any pre-emptive or other subscription rights. Holders of the Common Shares are entitled to cast one vote for each share held at all shareholders’ meetings for all purposes, including the election of directors. The Common Shares do not have cumulative voting rights.

None of the Preferred Shares are currently outstanding.

Action Necessary to Change Rights of Shareholders

Under the Company's Articles, the Board of Directors has the authority, without further action by the holders of the outstanding Common Shares, to issue preferred shares from time to time in one or more series, to fix the number of shares constituting any series, and to fix the terms of any such series, including dividend rights, dividend rates, conversion or exchange rights, voting rights, rights and terms of redemption (including sinking fund provisions), the redemption price and the liquidation preference or such series.

There are no limitations upon the rights to own securities.

There are no provisions that would have the effect of delaying, deferring, or preventing a change in control of the Company.

There is no special ownership threshold above which an ownership position must be disclosed.

A copy of the Company’s Articles has been filed as an exhibit to the Company’s 20-F Registration Statement.

Manner of Convening Annual and Special Meetings of Shareholders

Annual and special meetings of the shareholders may be called by the Board of Directors. Notice of a shareholder meeting shall be given not less than 21 days, and not more than 60 days, prior to the date of such meeting to each Director, the auditor of the Company and each shareholder of record entitled to vote at the meeting. A quorum for any shareholder meeting shall be persons present not being less than two in number and holding or representing by proxy not less than 5% of the total number of issued shares entitled to vote at the meeting.

Limitations on Rights to Own, Hold or Vote Securities

There are currently no limitations of general application imposed by Canadian federal or provincial laws on the rights of non-residents of Canada to hold or vote Strata’s common shares. There are also no such limitations imposed by the Articles of Incorporation with respect to Strata’s common shares. There are, however, certain requirements on the acquisition of control of Strata’s securities by non-residents of Canada. The Investment Canada Act requires notification to, and in certain cases, advance review and approval by the Government of Canada of the acquisition by a “non-Canadian” of “control” of a “Canadian business”, all as defined in the Investment Canada Act. Generally speaking, in order for an acquisition to be subject to advance review and approval, the asset value of the Canadian business being acquired must meet or exceed certain monetary thresholds.

C. Material Contracts

We have not entered into any material contracts, other than contracts entered into in the ordinary course of business, for the two years immediately preceding publication of this document. Significant property contracts are as described in Item 4.D.

D. Exchange Controls

There are no government laws, decrees or regulations in Canada which restrict the export or import of capital or, subject to the following sentence, which affect the remittance of dividends or other payments to nonresident holders of Strata’s common shares. However, any such remittance to a resident of the United States is generally subject to non-resident tax pursuant to the 1980 Canada-United States Income Tax Convention. See “Item 10.E Taxation” for additional discussion on tax matters.

E. Taxation

NOTHING HEREIN SHOULD BE RELIED UPON OR INTERPRETED AS LEGAL OR TAX ADVICE AND EACH SHAREHOLDER SHOULD CONSULT WITH HIS OR HER OWN ATTORNEY, ACCOUNTANT AND OTHER PROFESSIONAL ADVISORS ABOUT THE TAX CONSEQUENCES OF AN INVESTMENT IN THE COMPANY’S SECURITIES. THE DISCUSSION IS PRESENTED FOR INFORMATION PURPOSES ONLY AND IS INTENDED TO BE A DISCUSSION PRIMARILY OF THE CANADIAN AND UNITED STATES INCOME TAX CONSEQUENCES. EACH SHAREHOLDER IS URGED TO CONSULT WITH HIS OR HER PROFESSIONAL TAX ADVISER WITH RESPECT TO ALL FEDERAL, PROVINCIAL, STATE AND LOCAL INCOME TAXES, GIFT, ESTATE AND OTHER TAX CONSEQUENCES IN THE UNITED STATES AND CANADA. THE TAX AND OTHER MATTERS DESCRIBED HEREIN DO NOT CONSTITUTE AND SHOULD NOT BE CONSIDERED AS LEGAL OR TAX ADVICE TO SHAREHOLDERS.

CANADIAN FEDERAL INCOME TAX CONSEQUENCES

This summary is based upon the current provisions of the Income Tax Act (Canada), the regulations thereunder, the current publicly announced administrative and assessing policies of the Canada Revenue Agency, and all specific proposals (the “Tax Proposals”) to amend the Income Tax Act and regulations announced by the Minister of Finance (Canada) prior to the date hereof. This discussion is not exhaustive of all possible Canadian federal income tax consequences and, except for the Tax Proposals, does not take into account or anticipate any changes in law, whether by legislative, governmental or judicial action, nor does it take into account provincial or foreign tax considerations which may differ significantly from those discussed herein.

The summary applies to beneficial owners of common shares who, for the purposes of the Income Tax Act, are residents of the United States and are not resident in Canada, and who hold common shares of Strata as capital property.

Dividends

The Income Tax Act provides that dividends and other distributions deemed to be dividends paid or deemed to be paid by a Canadian resident corporation (such as Strata) to a non-resident of Canada shall be subject to a non-resident withholding tax equal to 25% of the gross amount of the dividend or deemed dividend.

Provisions in the Income Tax Act relating to dividend and deemed dividend payments to and capital gains realized by non-residents of Canada who are residents of the United States are subject to the 1980 Canada-United States Income Tax Convention and the five subsequent protocols amending the Convention.

Article X of the 1980 Canada-United States Income Tax Convention provides that the rate of Canadian non-resident withholding tax on dividends or deemed dividends paid to a United States corporation that beneficially owns at least 10% of the voting shares of the corporation paying the dividend shall not exceed 5% of the dividend or deemed dividend, and in any other case, the rate of non-resident withholding tax shall not exceed 15% of the dividend or deemed dividend.

Disposition of Shares

The Income Tax Act provides that a non-resident person is subject to tax in Canada on the disposition of “taxable Canadian property.” Common shares of Strata are likely considered to be “taxable Canadian property” as defined in the Income Tax Act. Therefore, under the Income Tax Act, a non-resident would be subject to tax in Canada on the disposition of common shares of Strata. Article XIII of the 1980 Canada-United States Income Tax Convention provides that gains realized by a United States resident on the disposition of shares of a Canadian corporation may not generally be taxed in Canada unless the value of the Canadian corporation is derived principally from real property situated in Canada.

Generally, certain filing and reporting obligations exist where a non-resident of Canada disposes of taxable Canadian property. In particular, the non-resident must make an application to the Canada Revenue Agency in advance of the disposition for the purpose of obtaining a certificate issued by the Canada Revenue Agency pursuant to section 116 of the Income Tax Act. If the non-resident fails to secure such certificate from the Canada Revenue Agency in advance of the disposition, the purchaser is required to withhold and remit to the Canada Revenue Agency 25% of the amount otherwise payable to the non-resident.

UNITED STATES FEDERAL INCOME TAX CONSEQUENCES

The following discussion is based on the U.S. Internal Revenue Code of 1986, as amended (the “Code”), existing and proposed Treasury Regulations, published Internal Revenue Service rulings, published administrative positions of the Internal Revenue Service and court decisions that are currently applicable, any or all of which could be materially and adversely changed, possibly on a retroactive basis, at any time. In addition, this discussion does not consider the potential effects, both adverse and beneficial, of any recently proposed legislation that, if enacted, could be applied, possibly on a retroactive basis, at any time. In addition, this discussion does not cover any state, local or foreign tax consequences. The following is a discussion of United States federal income tax consequences, under current law, generally applicable to a U.S. Holder (as defined below) of common shares of Strata who holds such shares as capital assets. This discussion does not address all potentially relevant federal income tax matters and it does not address consequences peculiar to persons subject to special provisions of federal income tax law, such as those described below that are excluded from the definition of a U.S. Holder.

U.S. Holder

As used herein, a “U.S. Holder” includes a holder of common shares of Strata who is a citizen or resident of the United States, a corporation created or organized in or under the laws of the United States or of any political subdivision thereof, any United States entity which is taxable as a corporation for United States tax purposes and any other person or entity whose ownership of common shares of Strata is effectively connected with the conduct of a trade or business in the United States. A U.S. Holder does not include persons subject to special provisions of federal income tax law, such as tax-exempt organizations, qualified retirement plans, financial institutions, insurance companies, real estate investment trusts, regulated investment companies, broker-dealers, nonresident alien individuals or foreign corporations whose ownership of common shares is not effectively connected with the conduct of a trade or business in the United States and shareholders who acquired their shares through the exercise of employee stock options or otherwise as compensation.

Dividends

Except as otherwise discussed below under “Passive Foreign Investment Company Considerations,” U.S. Holders receiving dividend distributions (including constructive dividends) with respect to common shares of Strata are required to include in gross income for United States federal income tax purposes the gross amount of such distributions to the extent that Strata has current or accumulated earnings and profits, without reduction for any Canadian income tax withheld from such distributions. Such Canadian tax withheld may be credited, subject to certain limitations, against the U.S. Holder’s United States federal tax liability or, alternatively, may be deducted in computing the U.S. Holder’s federal taxable income (but in the case of individuals, only if they itemize deductions). See “Foreign Tax Credit.” To the extent that distributions exceed current or accumulated earnings and profits of Strata, they will be treated first as a return of capital up to the U.S. Holder’s adjusted basis in the common shares (which adjusted basis must therefore be reduced) and thereafter as a gain from the sale or exchange of the common shares. Preferential tax rates for long-term capital gains are applicable to a U.S. Holder that is an individual, estate or trust. Moreover, “qualified dividends” received by U.S. Holders who are individuals, during tax years beginning before January 1, 2009, from any “qualified foreign corporation” are subject to a preferential tax rate, provided such individual U.S. Holder meets a certain holding period requirement. A “qualified foreign corporation” is generally any corporation formed in a foreign jurisdiction which has a comprehensive income tax treaty with the United States or, if not, the dividend is paid with respect to stock that is readily tradable on an established United States market. However, a “qualified foreign corporation” excludes a foreign corporation that is a foreign personal holding company, a foreign investment company, or a passive foreign investment company for the year the dividend is paid or the previous year. Strata believes that it qualifies as a “qualified foreign corporation”. There are currently no preferential tax rates for a U.S. Holder that is a corporation.

In general, dividends paid on common shares of Strata will not be eligible for the same dividends received deduction provided to corporations receiving dividends from certain United States corporations. A U.S. Holder which is a corporation may, under certain circumstances, be entitled to a 70% deduction of the United States source portion of dividends received from Strata (unless Strata is a “foreign personal holding company” as defined in Section 552 of the Code, or a “passive foreign investment company” as defined below) if such U.S. Holder owns shares representing at least 10% of the voting power and value of Strata. The availability of this deduction is subject to several complex limitations that are beyond the scope of this discussion.

Foreign Tax Credit

A U.S. Holder who pays (or has withheld from distributions) Canadian or other foreign income tax with respect to the ownership of common shares of Strata may be entitled, at the election of the U.S. Holder, to either a tax credit or a deduction for such foreign tax paid or withheld. This election is made on a year-by-year basis and generally applies to all foreign income taxes paid by (or withheld from) the U.S. Holder during that year. There are significant and complex limitations that apply to the credit, among which is the general limitation that the credit cannot exceed the proportionate share of the U.S. Holder’s United States income tax liability that the U.S. Holder’s foreign source income bears to his or its worldwide taxable income. In the determination of the application of this limitation, the various items of income and deduction must be classified into foreign and domestic sources. Complex rules govern income such as “passive income”, “high withholding tax interest”, “financial services income”, “shipping income” and certain other classifications of income. In addition, U.S. Holders that are corporations and that own 10% or more of the voting stock of Strata may be entitled to an “indirect” foreign tax credit under Section 902 of the Code with respect to the payment of dividends by Strata under certain circumstances and subject to complex rules and limitations. The availability of the foreign tax credit and the application of the limitations on the foreign tax credit are fact specific and holders and prospective holders of common shares should consult their own tax advisors regarding their individual circumstances.

Disposition of Shares

Except as otherwise discussed below under “Passive Foreign Investment Company Considerations,” a gain or loss realized on a sale of common shares will generally be a capital gain or loss, and will be long-term if the shareholder has a holding period of more than one year. The amount of gain or loss recognized by a selling U.S. Holder will be measured by the difference between (i) the amount realized on the sale and (ii) his or its tax basis in the common shares. Gains and losses are netted and combined according to special rules in arriving at the overall capital gain or loss for a particular tax year. Deductions for net capital losses are subject to significant limitations. Individual U.S. Holders may carryover unused capital losses to offset capital gains realized in subsequent years. For U.S. Holders that are corporations (other than corporations subject to Subchapter S of the Code), any unused capital losses may only be carried back three and forward five years from the loss year to offset capital gains until such net capital losses are exhausted.

Foreign Personal Holding Company Considerations

Special rules apply to a U.S. Holder of a “foreign personal holding company” or “FPHC” as defined in Section 552 of the Code. Strata will not be classified as a FPHC for U.S. federal income tax purposes unless (i) five or fewer individuals who are U.S. citizens or residents own or are deemed to own more than 50% of the total voting power of all classes of stock entitled to vote or the total value of Strata stock; and (ii) at least 60% (or 50% in certain cases) of Strata’s gross income consists of “foreign personal holding company income,” which generally includes passive income such as dividends, interest, gains from the sale or exchange of stock or securities, certain rents, and royalties. Strata believes that it is not a FPHC; however, no assurance can be provided that Strata will not be classified as a FPHC in the future.

Passive Foreign Investment Company Considerations

If Strata is a “passive foreign investment company” or “PFIC” as defined in Section 1297 of the Code, U.S. Holders will be subject to U.S. federal income taxation under one of two alternative tax regimes at the election of each such U.S. Holder. Section 1297 of the Code defines a PFIC as a corporation that is not formed in the United States and either (i) 75% or more of its gross income for the taxable year is “passive income”, which generally includes interest, dividends and certain rents and royalties or (ii) the average percentage, by fair market value (or, if Strata elects, adjusted tax basis), of its assets that produce or are held for the production of “passive income” is 50% or more. The rules applicable to a FPHC take priority over the rules applicable to a PFIC, so that amounts includable in gross income under the FPHC rules will not be taxable again under the PFIC rules. Strata does not believe that it will be a PFIC for the current fiscal year or for future years. Whether Strata is a PFIC in any year and the tax consequences relating to PFIC status will depend on the composition of Strata’s income and assets, including cash. U.S. Holders should be aware, however, that if Strata becomes a PFIC, it may not be able or willing to satisfy record-keeping requirements that would enable U.S. Holders to make an election to treat Strata as a “qualified electing fund” for purposes of one of the two alternative tax regimes applicable to a PFIC. U.S. Holders or potential shareholders should consult their own tax advisor concerning the impact of these rules on their investment in Strata.

F. Dividends and Paying Agents

Not applicable.

G. Statement by Experts

Not applicable.

H. Documents on Display

We are subject to the periodic reporting and other informational requirements of the Exchange Act. Under the Exchange Act, we are required to file reports and other information with the SEC. Specifically; we are required to file annually a Form 20-F Annual Report no later than four months after the close of each fiscal year which is December 31. Copies of reports and other information, when so filed, may be inspected without charge and may be obtained at prescribed rates at the public reference facilities maintained by the SEC at 100 F Street, N.E., Room 1580, Washington, D.C. 20549. The public may obtain information regarding the Washington, D.C. Public Reference Room by calling the SEC at 1-800-SEC-0330. The SEC also maintains a web site at www.sec.gov that contains reports, proxy and information statements, and other information regarding registrants that make electronic filings with the SEC using its EDGAR system. As a foreign private issuer, we are exempt from the rules under the Exchange Act prescribing the furnishing and content of quarterly reports and proxy statements, and officers, directors and principal shareholders are exempt from the reporting and short-swing profit recovery provisions contained in Section 16 of the Exchange Act.

The Company's documents on display are available with the U.S. Securities and Exchange Commission EDGAR website at www.sec.gov.

I. Subsidiary Information

Not applicable.

Item 11. Quantitative and Qualitative Disclosures About Market Risk

Market risk represents the potential risk of loss in the future earnings of Strata due to adverse changes in financial markets. Strata is exposed to market risk from changes in its common share price, foreign exchange rates and interest rates. Inflation has not had a significant impact on Strata’s results of operations.

Foreign Currency Sensitivity

While our financial statements are reported in US dollars and are intended to comply with U.S. GAAP requirements, a significant portion of our business operations may be conducted in Canadian dollars. Since June 1, 1970, the government of Canada has permitted a floating exchange rate to determine the value of the Canadian dollar as compared to the United States dollar. On March 23, 2015, the exchange rate in effect for Canadian dollars exchanged for United States dollars, expressed in terms of Canadian dollars was $1.25 This exchange rate is based upon the noon buying rates of the Bank of Canada.

Interest Rate Sensitivity

The Company currently has no significant long-term or short-term debt requiring interest payments. Thus, the Company has not entered into any agreement or purchased any instrument to hedge against possible interest rate risks at this time.

The Company's interest earning investments are primarily short-term, or can be held to maturity, and thus, any reductions in carrying values due to future interest rate declines are believed to be immaterial. However, as the Company has a significant cash or near-cash position, which is invested in such instruments, reductions in interest rates will reduce the interest income from these investments.

Item 12. Description of Securities Other than Equity Securities

Not applicable.

PART II

Item 13. Defaults, Dividend Arrearages and Delinquencies

None.

Item 14. Material Modifications to the Rights of Security Holders and Use of Proceeds

None.

Item 15. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

Our management, under supervision and with the participation of the principal executive officer and the principal financial officer, evaluated the effectiveness of our disclosure controls and procedures, as defined under Exchange Act Rule 13a-15(e). Based upon this evaluation, the principal executive officer and principal financial officer concluded that, as of December 31, 2014, our disclosure controls and procedures were effective.

Disclosure controls and procedures are controls and other procedures that are designed to ensure that information required to be disclosed in our reports filed or submitted under the Securities Exchange Act is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed in our reports filed under the Exchange Act is accumulated and communicated to our management, including our principal executive officer and our principal financial officer, as appropriate, to allow timely decisions regarding required disclosure.

Management’s Report on Internal Controls over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting, as defined under Exchange Act Rules 13a-15(f) and 15d-15(f). Our internal control over financial reporting is designed 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.

All internal control systems, no matter how well designed, have inherent limitations and may not prevent or detect misstatements. Therefore, even those systems determined to be effective can only provide reasonable assurance with respect to financial reporting reliability and financial statement preparation and presentation. In addition, projections of any evaluation of effectiveness to future periods are subject to risk that controls become inadequate because of changes in conditions and that the degree of compliance with the policies or procedures may deteriorate.

Management assessed the effectiveness of the Company’s internal control over financial reporting as of December 31, 2014. In making the assessment, management used the criteria issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO) in Internal Control-Integrated Framework (2013). Based on its assessment, management concluded that, as of December 31, 2014, the Company’s internal control over financial reporting was effective.

As defined by Auditing Standard No. 5, “An Audit of Internal Control Over Financial Reporting that is Integrated with an Audit of Financial Statements and Related Independence Rule and Conforming Amendments,” established by the Public Company Accounting Oversight Board (“PCAOB”), a material weakness is a deficiency or combination of deficiencies that results in more than a remote likelihood that a material misstatement of annual or interim financial statements will not be prevented or detected. In connection with the assessment described above, management concluded the Company does not have control deficiencies that represent material weaknesses as of December 31, 2014.

Attestation Report of Registered Public Accounting Firm

This Annual Report does not include an attestation report of the Company’s independent registered public accounting firm regarding internal control over financial reporting. Management’s report was not subject to attestation by the Company’s independent registered public accounting firm pursuant to permanent rules of the SEC that permit the Company to provide only management’s report in this Annual Report.

Changes in Internal Controls over Financial Reporting

As of December 31, 2014, management assessed the effectiveness of our internal control over financial reporting, and based on that evaluation, they concluded that through December 31, 2014 and to date, the internal controls and procedures were effective. During the course of their evaluation, we did not discover any fraud involving management or any other personnel who play a significant role in our disclosure controls and procedures or internal controls over financial reporting.

We believe that our financial statements contained in our Form 20-F for the twelve months ended December 31, 2014, fairly present our financial position, results of operations and cash flows for the years covered thereby in all material respects. We are committed to improving our financial organization. We will continue to monitor and evaluate the effectiveness of our internal controls and procedures and our internal controls over financial reporting on an ongoing basis and are committed to taking further action and implementing additional enhancements or improvements as necessary.

Item 16A. Audit Committee

The Board of Directors is empowered to appoint an Audit Committee for the Corporation. Currently the Board of Directors functions as the Audit Committee. The Audit Committee members are not considered independent as specified in the National Instrument 52-110. We believe that the Board of Directors are collectively capable of analyzing and evaluating our financial statements and understanding internal controls and procedures for financial reporting. In addition, we believe that retaining an independent director who would qualify as an “audit committee financial expert” would be overly costly and burdensome and is not warranted in our circumstances given the early stages of our development and the fact that we have not generated revenues to date.

Pursuant to National Instrument 52-110 Part 6 (6.1) as a venture issuer, Strata is exempt from the requirements of Parts 3 (Composition of the Audit Committee) and 5 (Reporting Obligations).

Item 16B. Code of Ethics

The Company has adopted a Code of Ethics that applies to its principal executive officer, principal financial officer, principal accounting officer or controller, or persons performing similar functions. For purposes of this Item, the term Code of Ethics means written standards that are reasonably designed to deter wrongdoing and to promote:

honest and ethical conduct, including the ethical handling of actual or apparent conflicts of interest between personal and professional relationships;

full, fair, accurate, timely, and understandable disclosure in reports and documents that the issuer files with, or submits to, the Commission and in other public communications made by the issuer;

compliance with applicable governmental laws, rules and regulations;

the prompt internal reporting of violations of the code to the board of directors or another appropriate person or persons identified in the code; and

accountability for adherence to the code.

There have been no amendments to the Code of Ethics and no waivers of any of its provisions during the year ended December 31, 2014.

The Company hereby undertakes to provide to any person without charge, upon request, a copy of such Code of Ethics. Such request may be made in writing to the Board of Directors at the address of the issuer.

Item 16C. Principal Accountant Fees and Services

The fees billed for each of the last two fiscal years for professional services rendered by the Company’s audit firm for various services (including an estimate of year-end audit fees) are set forth below:

	Fiscal year ending December 31, 2014 (1)(2)		Fiscal year ending December 31, 2013 (1)
Audit Fees	$	15,800	$	15,400
Audit Related Fees				–
Tax Fees				–
All Other Fees				–
	$	15,800	$	15,400

(1)	As of December 31, 2014, the Company’s Audit Committee did not have a formal documented pre-approval policy for the fees of the principal accountant.
(2)	Estimated to date for the year ended December 31, 2014

From time to time, management of the Company recommends to and requests approval from the Board of Directors for non-audit services to be provided by the Company’s auditors. The Board routinely considers such requests during Board meetings, and if acceptable to a majority of the Board members, pre-approves such non-audit services by a resolution authorizing management to engage the Company’s auditors for such non-audit services, with set maximum dollar amounts for each itemized service. During such deliberations, the Board assesses, among other factors, whether the services requested would be considered “prohibited services” as contemplated by the Securities and Exchange Commission and whether the services requested and the fees related to such services could impair the independence of the auditors. There were no non-audit related services provided by the Company’s audit firm.

Item 16D. Exemptions from the Listing Standards for Audit Committees

Not applicable.

Item 16E. Purchases of Equity Securities by the Issuer and Affiliated Purchasers

Neither the Company nor any “affiliated purchasers” as defined in Rule 10b-18(a)(3) under the Exchange Act purchased any shares of the Company.

Item 16F. Change in Registrant’s Certifying Accountant

Not applicable.

Item 16G. Corporate Governance

Not applicable.

Item 16H. Mine Health and Safety, Conflict Minerals and Government Payments

Not applicable.

PART III

Item 17. Financial Statements

The Company has provided financial statements pursuant to Item 18.

Item 18. Financial Statements

The Company's financial statements are stated in United States Dollars and are prepared in accordance with U.S. Generally Accepted Accounting Principles (GAAP).

The financial statements provided under this item are listed in the table of contents below, and the audit report of Peterson Sullivan LLP immediately precedes the audited financial statements.

Item 19. Exhibits

Exhibit No.	Description
1.1	Articles of Continuance(1)
1.2	Bylaws(1)
1.3*	Audit Committee Charter
2.1	Description of Capital Stock (contained in the Articles of Continuance filed as Exhibit 1.1)
12.1*	Section 302 Certification of Principal Executive and Financial Officer
13.1*	Section 906 Certification of Principal Executive and Financial Officer
14.1*	Peterson Sullivan Consent
15.2	2006 Stock Option Plan (2)
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 herewith.

(1) Previously filed with the Company’s Registration Statement on Form S-4 on April 22, 2003

(2) Filed with the Company’s Form S-8 Registration Statement on June 1, 2006

SIGNATURES

The Registrant hereby certifies that it meets all of the requirements for filing on Form 20-F and that it has duly caused and authorized the undersigned to sign this Annual Report on its behalf.

	STRATA OIL & GAS INC.
	(Registrant)

Dated: April 29, 2015	By: /s/ Ron Daems
	Ron Daems
	President, Chief Executive Officer,
	Secretary and Director

In accordance with the Exchange Act, this report has been signed below by the following persons on behalf of the Registrant and in the capacities and on the dates indicated.

SIGNATURE	TITLE	DATE

/s/ Ron Daems	President, Chief Executive Officer, Secretary and Director	April 29, 2015
Ron Daems

/s/ Trevor Newton	Director	April 29, 2015
Trevor Newton

/s/ Michael Ranger	Director	April 29, 2015
Michael Ranger

Strata Oil & Gas Inc.

FINANCIAL STATEMENTS

December 31, 2014

(Stated in US Dollars)

Strata Oil & Gas Inc.

Financial Statements

December 31, 2014

Contents

Report of Independent Registered Public Accounting Firm	F-2

Financial Statements

Balance Sheets	F-3
Statements of Operations and Comprehensive Income (Loss)	F-4
Statements of Changes in Stockholders’ Equity	F-5
Statements of Cash Flows	F-6
Notes to the Financial Statements	F-7

F-1

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholders

Strata Oil & Gas Inc.

We have audited the accompanying balance sheets of Strata Oil & Gas Inc. ("the Company") as of December 31, 2014 and 2013, and the related statements of operations and comprehensive income (loss), changes in stockholders' equity, and cash flows for each of the three years in the period ended December 31, 2014. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company has determined that it is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over financial reporting. Accordingly, we express no such opinion. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Strata Oil & Gas Inc. as of December 31, 2014 and 2013, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2014, in conformity with accounting principles generally accepted in the United States.

The accompanying financial statements have been prepared assuming the Company will continue as a going concern. As discussed in Note 2 to the financial statements, the Company has not been able to generate any operating revenue to date and has an accumulated deficit of $18,946,856 at December 31, 2014. In addition, the Company had negative cash flows from operations of $247,614 during the year ended December 31, 2014. These conditions raise substantial doubt about the Company's ability to continue as a going concern. Management's plans regarding those matters are also described in Note 2. The financial statements do not include any adjustments that might result from the outcome of this uncertainty.

/S/ PETERSON SULLIVAN LLP

Seattle, Washington

April 29, 2015

F-2

STRATA OIL & GAS INC.

BALANCE SHEETS

(Expressed in US Dollars)

	December 31,
	2014			2013
ASSETS
Current
Cash	$	118,873		$	440,612
GST Receivables		9,001			6,385
Notes receivable from related parties		163,793			65,814
Prepaid expenses		4,012			–
Total current assets		295,680			512,811

Deposits		133,745			121,870
Office equipment, net		–			–
Oil and gas property interest (unproved)		7,423,966			7,784,848
Total assets	$	7,853,390		$	8,419,529

LIABILITIES AND STOCKHOLDERS' EQUITY
Liabilities
Current
Accounts payable	$	48,922		$	1,526
Accrued liabilities		32,387			–
Derivative liability		4,482,926			5,178,906
Total current liabilities		4,564,235			5,180,432

Asset retirement obligation		138,049			139,623
Total liabilities		4,702,284			5,320,055
Stockholders' equity
Preferred stock, no par value, unlimited shares authorized and unissued		–			–
Common stock, no par value, unlimited shares authorized; 89,383,183 and 85,728,506 shares issued and outstanding at December 31, 2014 and 2013, respectively.		–			–
Additional paid-in capital		21,905,643			21,304,071
Accumulated deficit		(18,946,856	)		(18,663,755	)
Foreign currency translation adjustments		192,319			459,158
Total stockholders' equity		3,151,106			3,099,474
Total liabilities and Stockholders' equity	$	7,853,390		$	8,419,529

The accompanying notes are an integral part of these financial statements

F-3

STRATA OIL & GAS INC.

STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME (LOSS)

(Expressed in US Dollars)

	For the years ended December 31,
	2014			2013			2012
Expenses
Professional fees	$	125,868		$	86,834		$	76,154
Office and sundry		30,070			24,018			32,845
Rent		308			1,665			1,667
Consulting fees		584,019			448,338			120,799
Transfer agent fees		2,478			3,267			1,642
Accretion expense		10,545			10,487			7,500
Depreciation		–			–			1,388
		753,287			574,609			241,995
Other income (expense)
Interest and miscellaneous income		1,287			1,339			5,524
Interest income, related party		3,637			–			–
Foreign exchange loss		(1,237	)		(8,780	)		–
Change in fair value of derivative liability		466,499			(2,216,119	)		(1,620,319	)
		470,186			(2,223,559	)		(1,614,795	)

Net income (loss)		(283,101	)		(2,798,169	)		(1,856,790	)

Other comprehensive income (loss)
Foreign currency translation adjustment		(266,839	)		(280,325	)		168,351

Comprehensive income (loss)	$	(549,940	)	$	(3,078,494	)	$	(1,688,439	)

Basic and diluted earnings (loss) per share (Note 8)
Basic income (loss) per common share	$	(0.00	)	$	(0.04	)	$	(0.03	)

Basic weighted average number of shares outstanding		87,191,251			80,057,824			71,340,773

The accompanying notes are an integral part of these financial statements

F-4

STRATA OIL & GAS INC.

STATEMENTS OF CHANGES IN STOCKHOLDERS’ EQUITY

(Expressed in US Dollars)

	Common Stock		Additional Paid-in			Accumulated			Accumulated Other Comprehensive			Total Stockholders'
	Shares		Capital			Deficit			Income			Equity
Balance December 31, 2011		69,412,043	$	21,028,596		$	(14,008,796	)	$	571,132		$	7,590,932

Stock compensation, non-employees				40,826									40,826
Private placement, common stock and warrants issuance for cash		5,231,667		226,400									226,400
Derivative liability adjustment				(226,400	)								(226,400	)
Net loss and comprehensive income							(1,856,790	)		168,351			(1,688,439	)
Balance December 31, 2012		74,643,710		21,069,422			(15,865,586	)		739,483			5,943,319

Stock compensation, non-employees				80,080									80,080
Reclassification of warrant derivative liability due to warrant exercise				117,069									117,069
Warrant exercise		625,000		37,500									37,500
Private placement, common stock and warrants issuance for cash		10,459,796		969,502									969,502
Derivative liability adjustment				(969,502	)								(969,502	)
Net loss and comprehensive loss							(2,798,169	)		(280,325	)		(3,078,494	)
Balance December 31, 2013		85,728,506		21,304,071			(18,663,755	)		459,158			3,099,474

Stock compensation, non-employees				421,923									421,923
Reclassification of warrant derivative liability due to warrant exercise				110,049									110,049
Warrant exercise		652,500		69,600									69,600
Private placement, common stock and warrants issuance for cash		3,002,177		301,600									301,600
Derivative liability adjustment				(301,600	)								(301,600	)
Net loss and comprehensive loss							(283,101	)		(266,839	)		(549,940	)
Balance December 31, 2014		89,383,183	$	21,905,643		$	(18,946,856	)	$	192,319		$	3,151,106

The accompanying notes are an integral part of these financial statements

F-5

STRATA OIL & GAS INC.

STATEMENTS OF CASH FLOWS

(Expressed in US Dollars)

	For the years ended December 31,
	2014			2013			2012
Cash flows from operating activities
Net income (loss)	$	(283,101	)	$	(2,798,169	)	$	(1,856,790	)
Adjustments to reconcile net income (loss) to net cash used in operating activities
Accrued interest		(3,637	)		–			–
Depreciation		–			–			1,388
Stock option expense for consulting fees		421,923			80,080			40,826
Accretion expense		10,545			10,487			7,500
Change in fair value of derivative liability		(466,499	)		2,216,119			1,620,319
Change in assets and liabilities
GST receivable		(2,616	)		(6,165	)		14,871
Prepaid expenses		(4,012	)		5,002			3,734
Accounts payable		47,396			(17,933	)		(11,528	)
Accrued liabilities		32,387			(14,970	)		(11,213	)
Net cash used in operating activities		(247,614	)		(525,549	)		(190,894	)

Cash flows from investing activities
Deposits		(23,892	)		(6,152	)		(7,462	)
Acquisition of oil & gas interests		(298,786	)		(107,391	)		(113,541	)
Notes receivable advances to related parties		(103,309	)		(65,814	)		–
Net cash used in investing activities		(425,989	)		(179,357	)		(121,003	)

Cash flows from financing activities
Proceeds from issuance of common stock and warrants		301,600			969,502			226,400
Proceeds from the exercise of warrants		69,600			37,500			–
Net cash provided by financing activities		371,200			1,007,002			226,400
Foreign exchange effect on cash		(19,338	)		4,391			2,118
Net increase (decrease) in cash		(321,739	)		306,487			(83,379	)
Cash, beginning balance		440,612			134,125			217,504
Cash, ending balance	$	118,873		$	440,612		$	134,125

Supplemental disclosure of cash paid for:
Interest	$	–		$	–		$	–
Income taxes	$	–		$	–		$	–

The accompanying notes are an integral part of these financial statements

F-6

Notes to the Financial Statements

1. NATURE OF BUSINESS AND OPERATIONS

Strata Oil & Gas Inc. (the ‘Company’) is engaged in the exploration for oil and natural gas in oil sands in the Canadian province of Alberta. The Company was formerly engaged in the development of Knowledge Worker Automation (KWA) software.

Upon disposal of the Company’s software assets a majority of the Company’s shareholders approved a change the business of the Company from software development to oil and gas exploration. The Company is currently engaged in the acquisition exploration, and if warranted and feasible development of oil and gas properties

The Company’s activities are subject to significant risks and uncertainties. We have only recently commenced oil and gas exploration operations. Our prospects must be considered in light of the risks, expenses and difficulties frequently encountered in establishing a business in the oil and natural gas industries. We have yet to generate any revenues from operations. There is nothing at this time on which to base an assumption that our business operations will prove to be successful or that we will ever be able to operate profitably. Our future operating results will depend on many factors, including:

our ability to raise adequate working capital;

success of our exploration and development efforts;

demand for natural gas and oil;

the level of our competition;

our ability to attract and maintain key management and employees; and

our ability to efficiently explore, develop and produce sufficient quantities of marketable natural gas or oil in a highly competitive and speculative environment while maintaining quality and controlling costs.

To achieve profitable operations, we must, alone or with others, successfully execute on the factors stated above. There are no assurances that the Company will be able to execute its plan and if we are not successful in executing any of the above stated factors, our business will not be profitable and may never even generate any revenue, which make our common shares a less attractive investment and may harm the trading of our common shares.

2. ABILITY TO CONTINUE AS A GOING CONCERN

The accompanying financial statements have been prepared in US dollars and in accordance with accounting principles generally accepted in the United States on a going concern basis, which contemplates the realization of assets and the satisfaction of liabilities and commitments in the normal course of business. The Company commenced its oil and gas exploration activities in the last quarter of 2005. The Company has not realized any revenue from its present operations. During the year ended December 31, 2014, the Company incurred a loss of $283,101. In addition, the Company had negative cash flows from operations of $247,614 and is expected to continue to incur further negative operating cash flows in the foreseeable future. The Company has an accumulated deficit of $18,946,856 at December 31, 2014. These conditions raise substantial doubt about the Company's ability to continue as a going concern.

The Company's ability to continue as a going concern is dependent on its ability to develop its oil and gas properties and ultimately achieve profitable operations and to generate sufficient cash flow from financing and operations to meet its obligations as they become payable. The Company expects that it will need approximately $1,525,000 to fund its operations during the next twelve months which will include minimum annual property lease payments, expected exploration expenditures for permitting and drilling, as well as operating expenses. Management has plans to seek additional capital through a private placement and public offering of its common stock. Although there are no assurances that management’s plans will be realized, management believes that the Company will be able to continue operations in the future. Accordingly, no adjustment relating to the recoverability and classification of recorded asset amounts and the classification of liabilities has been made to the accompanying financial statements in anticipation of the Company not being able to continue as a going concern.

F-7

3. SIGNIFICANT ACCOUNTING POLICIES

Management’s Estimates and Assumptions

The preparation of financial statements in conformity with United States Generally Accepted Accounting Principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities as of the balance sheet date, and revenues and expenses for the period then ended. Actual results could differ significantly from those estimates

Oil and Gas Property Payments and Exploration Costs

The Company follows the full cost method of accounting for natural gas and oil operations. Under the full cost method all costs incurred in the acquisition, exploration and development of natural gas and oil interests are initially capitalized into cost centers on a country-by-country basis. The Company’s current cost center is located in Canada. Such costs include land acquisition costs, geological and geophysical expenditures, carrying charges on non-producing properties, costs of drilling and overhead charges directly related to acquisition, exploration and development activities.

Costs capitalized, together with the costs of production equipment, are depleted and amortized on the unit-of-production method based on the estimated net proved reserves, as determined by independent petroleum engineers. The accounting standards require that the average, first-day-of-the-month price during the 12-month period before the end of the year rather than the year-end price, must be used when estimating whether reserve quantities are economical to produce. This same 12-month average price is also used in calculating the aggregate amount of (and changes in) future cash inflows related to the standardized measure of discounted future net cash flows. Costs of acquiring and evaluating unproved properties are initially excluded from depletion calculations. These unproved properties are assessed periodically to ascertain whether impairment has occurred. When proved reserves are assigned or the property is considered to be impaired, the cost of the property or the amount of the impairment is added to costs subject to depletion calculations.

Under full cost accounting rules, capitalized costs, less accumulated amortization and related deferred income taxes, shall not exceed an amount (the ceiling) equal to the sum of: (i) the after tax present value of estimated future net revenues computed by applying current prices of oil and gas reserves to estimated future production of proved oil and gas reserves as of the date of the latest balance sheet presented, less estimated future expenditures (based on currents costs) to be incurred in developing and producing any proved reserves computed using a discount factor of ten percent and assuming continuation of existing economic conditions; (ii) the cost of properties not being amortized; and (iii) the lower of cost or estimated fair value of unproved properties included in the costs being amortized. If unamortized costs capitalized within a cost center, less related deferred income taxes, exceed the ceiling, the excess shall be charged to expense and separately disclosed during the period in which the excess occurs. Amounts thus required to be written off shall not be reinstated for any subsequent increase in the cost center ceiling. We do not have any proved reserves in our current property holdings.

On an annual basis management evaluates the carrying value of the Company’s unproved oil and gas properties and assesses them for impairment, considering historical experience and other data such as primary lease terms of the properties, average holding period of unproved properties and geographic and geologic data. Management noted no matters indicating the cost of the Company’s unproved properties was impaired at December 31, 2014 or 2013.

The Company has not recognized any revenue from its oil and gas exploration activities which commenced in the last quarter of 2005.

F-8

3. SIGNIFICANT ACCOUNTING POLICIES - continued

Cash and Cash Equivalents

The Company considers all highly liquid investments purchased with a maturity of 90 days or less to be cash equivalents. The company maintains cash and cash equivalent balances with financial institutions that may exceed federally insured limits. There was no cash equivalent balances for the year ended December 31, 2014 (2013 – $Nil).

GST Receivables

GST Receivables are presented net of an allowance for doubtful accounts. Receivables consist of goods and services input tax credits. The allowance was $Nil at both December 31, 2014 and 2013.

Office Equipment

Office equipment is recorded at cost less accumulated depreciation using the straight-line method over the estimated useful lives of the assets which is estimated to be five years.

	December 31, 2014			December 31, 2013
Office equipment	$	11,614		$	11,614
Accumulated depreciation		(11,614	)		(11,614	)
Net book value	$	–		$	–

Impairment of Long-lived Assets

In accordance with ASC 360, Property, Plant and Equipment, long lived assets such as equipment are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Recoverability of assets to be held and used is measured by a comparison of the carrying amount of an asset to estimated undiscounted future cash flows expected to be generated by the asset. If the carrying amount of an asset exceeds its estimated future cash flows, an impairment charge is recognized by the amount by which the carrying amount of the asset exceeds the fair value of the asset. Assets to be disposed of would be separately presented in the balance sheet and reported at the lower of the carrying amount of fair value less costs to sell, and are no longer depreciated. The assets and liabilities of a disposed group classified as held for sale would be presented separately in the appropriate asset and liability sections of the balance sheet.

Asset Retirement Obligations

In accordance with ASC 410, Asset Retirement and Environmental Obligations the fair value of an asset retirement cost, and corresponding liability, should be recorded as part of the cost of the related long-lived asset and subsequently allocated to expense using a systematic and rational method. The Company has recorded an asset retirement obligation at December 31, 2014 and 2013 (Note 7) to reflect its legal obligations related to future abandonment of its oil and gas interests using estimated expected cash flow associated with the obligation and discounting the amount using a credit-adjusted, risk-free interest rate. At least annually, the Company will reassess the obligation to determine whether a change in any estimated obligation is necessary. The Company will evaluate whether there are indicators that suggest the estimated cash flows underlying the obligation have materially changed. Should those indicators suggest the estimated obligation has materially changed the Company will accordingly update its assessment. The liability accretes until the Company settles the obligation.

F-9

3. SIGNIFICANT ACCOUNTING POLICIES - continued

Income Taxes

The Company follows the asset and liability method of accounting for income taxes whereby deferred tax assets and liabilities are recognized for the future tax consequences of differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. If it is determined that the realization of the future tax benefit is not more likely than not, the enterprise establishes a valuation allowance.

Foreign Exchange Translation

The Company's functional currency is the Canadian dollar, but reports its financial statements in US dollars. The Company translates its Canadian dollar balances to US dollars in the following manner: Assets and liabilities have been translated using the rate of exchange at the balance sheet date. The Company’s results of operations have been translated using average rates. Translation gains or losses resulting from the changes in the exchange rates are accumulated as other comprehensive income or loss in a separate component of stockholders' equity.

All amounts included in the accompanying financial statements and footnotes are stated in U.S. dollars.

Derivative Financial Instruments

The Company reviews the terms of its equity instruments and other financing arrangements to determine whether there are embedded derivative instruments that are required to be accounted for separately as a derivative financial instrument. Also, in connection with the issuance of financing instruments, the Company has issued freestanding warrants that are accounted for as derivative instrument liabilities because they are exercisable in a currency other than the functional currency of the Company and thus do not meet the “fixed-for-fixed” criteria of ASC 815-40-15. The warrants are exercisable in United States dollars and the Company’s functional currency is the Canadian dollar.

Derivative financial instruments are initially measured at their fair value. For derivative financial instruments that are accounted for as liabilities, the derivative instrument is initially recorded at its fair value and is then re-valued at each reporting date, with changes in the fair value reported as charges or credits to income. For option and warrant-based derivative financial instruments, the Company uses the Black-Scholes option pricing model to value the derivative instruments.

Any exercise or cancellation of an equity instrument which meets the classification of a derivative financial instrument is trued-up to fair value at that date and the fair value of the exercised instrument is then re-classed from liability to additional paid in capital.

The classification of derivative instruments, including whether such instruments should be recorded as liabilities or as equity, is reassessed at the end of each reporting period. If reclassification is required, the fair value of the derivative instrument, as of the determination date, is reclassified. Any previous charges or credits to income for changes in the fair value of the derivative instrument are not reversed. Derivative instrument liabilities are classified in the balance sheet as current or non-current based on whether or not net-cash settlement of the derivative instrument could be required within 12 months of the balance sheet date.

Stock Option Plans

The Company has elected to use the Black-Scholes option pricing model to determine the fair value of stock options granted. In accordance with the accounting standard for employees, the compensation expense is amortized on a graded vesting basis over the requisite service period which approximates the vesting period. There were no options issued to employees for the years ended December 31, 2014, 2013 or 2012.

Compensation expense for stock options granted to non-employees is amortized over the contract services period or, if none exists, from the date of grant until the options vest. Compensation associated with unvested options granted to non-employees is re-measured on each balance sheet date using the Black-Scholes option pricing model.

F-10

3. SIGNIFICANT ACCOUNTING POLICIES - continued

The expected volatility of options granted has been determined using the methods described under the relevant accounting standard. The Company uses historical data to estimate option exercise, forfeiture and employee termination within the valuation model. For non-employees, the expected term of the options approximates the full term of the options. The risk-free interest rate is based on a treasury instrument whose term is consistent with the expected term of the stock options. The Company has not paid and does not anticipate paying dividends on its common stock; therefore, the expected dividend yield is assumed to be zero. In addition, accounting standard requires companies to utilize an estimated forfeiture rate when calculating the expense for the reporting period. Based on its best estimate, management applied the estimated forfeiture rate of nil in determining the expense recorded in the accompanying Statements of Operations and Comprehensive Income (Loss).

Compensation expense is recognized immediately for past services and pro-rata for future services over the option vesting period. During 2014, the Company recognized $421,923 (2013 - $80,080 expense; 2012 - $40,826) in stock-based compensation expense in the Statements of Operations and Comprehensive Income (Loss) in respect of options granted to non-employees. All stock options granted in 2014, 2013, and 2012 were to non-employees of the Company.

The fair value of each option granted is estimated using the Black-Scholes option-pricing model over the vesting period. During the years ended December 31, 2014, 2013 and 2012 the following weighted average assumptions were used:

	2014			2013			2012
Dividend yield		0	%		0	%		0	%
Expected volatility		147.1	%		144.2	%		152.6	%
Risk-free rate		1.79	%		2.77	%		1.67	%
Expected life in years		10			8.5			10

The Company issued 3,770,000 stock options during 2014. The weighted average grant date fair value per option in 2014 was $0.14.

Expected volatilities are calculated using the historical volatility of the Company’s stock. When applicable, the Company will use historical data to estimate option exercise, forfeiture and employees termination within the valuation model. For non-employees, the expected term of the options approximates the full term of the options.

Earnings (Loss) Per Share of Common Stock

Basic earnings (loss) per share of common stock is computed by dividing net income (loss) available to common shareholders by the weighted-average number of common shares outstanding for the period. Diluted earnings per share of common stock reflect the potential dilution that could occur if securities or other contracts to issue common stock were exercised or converted into common stock or resulted in the issuance of common stock that then shared in the earnings of the Company. Dilutive potential common shares are calculated in accordance with the treasury stock method, which assumes that proceeds from the exercise of all warrants and options are used to repurchase common stock at market value. The amount of shares remaining after the proceeds are exhausted represents the potentially dilutive effect of the securities. Warrants and options with an exercise price lower than the weighted average share price during the period were determined to be anti-dilutive and excluded from the computation of earnings per share.

At December 31, 2014, 2013 and 2012, the effect of all outstanding options and common stock warrants would have been anti-dilutive, due to the net loss incurred and accordingly only basic earnings per share is presented for all years.

F-11

3. SIGNIFICANT ACCOUNTING POLICIES - continued

Fair Value of Financial Instruments

The book values of GST receivables, notes receivable, accounts payable and accrued expenses approximate their respective fair values due to the short-term nature of these instruments. The fair value hierarchy under GAAP distinguishes between assumptions based on market data (observable inputs) and an entity’s own assumptions (unobservable inputs). The hierarchy consists of three levels:

	•	Level one — Quoted market prices in active markets for identical assets or liabilities;
	•	Level two — Inputs other than level one inputs that are either directly or indirectly observable; and
	•	Level three — Unobservable inputs developed using estimates and assumptions, which are developed by the reporting entity and reflect those assumptions that a market participant would use.

Determining which category an asset or liability falls within the hierarchy requires significant judgment. We evaluate our hierarchy disclosures each quarter. Liabilities measured at fair value are summarized as follows as of:

December 31, 2014:

		Level 1				Level 2				Level 3				Total
Derivative liability		$	–			$	–			$	4,482,926			$	4,482,926

December 31, 2013:

		Level 1				Level 2				Level 3				Total
Derivative liability		$	–			$	–			$	5,178,906			$	5,178,906

We currently measure and report the fair value liability for warrants with a strike price currency different than the functional currency of the Company on a recurring basis. The fair value liabilities for warrants have been recorded as determined utilizing the Black-Scholes option pricing model. See Note 5 for further discussion of the inputs used in determining the fair value.

Comprehensive Income (Loss)

Comprehensive income (loss) is defined to include all changes in equity except those resulting from investments by owners and distributions to owners. The Company's items of other comprehensive income (loss) are foreign currency translation adjustments.

New Accounting Pronouncements

From time to time, new accounting pronouncements are issued by the Financial Accounting Standards Board (“FASB”) that are adopted by the Company as of the specified effective date. Unless otherwise discussed, management believes that the impact of recently issued standards did not or will not have a material impact on the Company’s consolidated financial statements upon adoption.

F-12

3. SIGNIFICANT ACCOUNTING POLICIES - continued

There are no other recently issued accounting pronouncements that are expected to have a material impact on our financial condition, results of operations or cash flows.

4. NOTES RECEIVABLE, RELATED PARTIES

On December 27, 2013 the Company entered into an unsecured short-term note agreement for $65,814 ($70,000 Canadian) with a related party through common director. The note bears interest at the Bank of Canada prime rate plus 1%. The borrower may repay the entire loan including outstanding interest at any time by advising the Company of the intent to pay fifteen days prior to the anticipated date of retirement.

For the year ended December 31, 2014 the Company advanced an additional $42,727 ($47,000 Canadian) under the short-term note agreements. The Company recognized $3,406 and $Nil in accrued interest income for the years ended December 31, 2014 and 2013, under the terms of the note agreements. The balance of the notes receivable, including accrued interest at December 31, 2014 was $104,096.

On November 13, 2014 and December 9, 2014 the Company entered into several unsecured short-term note agreements for an aggregate $60,582 ($69,000 Canadian) with a second related party (the Company and the related party have a common director). The notes bear interest at the Bank of Canada prime rate plus 1%. The borrower may repay the entire loan including outstanding interest at any time by advising the Company of the intent to pay fifteen days prior to the anticipated date of retirement.

The Company recognized $231 and $Nil in accrued interest income for the years ended December 31, 2014 and 2013, under the terms of the note agreements. The balance of the notes receivable, including accrued interest, at December 31, 2014 was $59,697.

Further to all aforementioned note agreement(s), the Company retains the right to enter into an option agreement with the borrower for development rights on its oil sands leases in Alberta. Any outstanding balances payable under the note agreement(s) may be applied towards option payments owing, should the Company elect to exercise its right to enter into an option agreement. Management expects the notes receivable to be paid or converted to an option agreement within one year and has classified the notes as a current assets on the balance sheet.

5. DERIVATIVE LIABILITIES

Derivative liabilities, consisting of the equity instruments such as common share warrants with an exercise price in a different currency than the Company’s functional currency, are accounted for as separate liabilities measured at their respective fair values as follows:

F-13

5. DERIVATIVE LIABILITIES continued

Balance, December 31, 2011	$	484,777

Fair value of warrants issued in private placements		226,400
Change in fair value of derivative liabilities		1,620,319
Foreign exchange effect on derivative liability		11,493
Balance, December 31, 2012		2,342,989

Fair value of warrants issued in private placements		969,502
Exercise of warrants – reclassification to additional paid-in-capital		(117,069	)
Change in fair value of derivative liabilities		2,216,119
Foreign exchange effect on derivative liability		(232,635	)
Balance, December 31, 2013		5,178,906

Fair value of warrants issued in private placements		301,600
Exercise of warrants – reclassification to additional paid-in-capital		(110,049	)
Change in fair value of derivative liabilities		(466,499	)
Foreign exchange effect on derivative liability		(421,032	)
Balance, December 31, 2014	$	4,482,926

The fair value of the derivative liabilities has been determined using the Black-Scholes option pricing model using the following range of assumptions:

	December 31,		December 31,		December 31,
	2014		2013		2012

Risk-free interest rate		1.01 to 1.79%		1.13 to 2.77%		1.21 to 1.80%
Expected life of derivative liability		1 to 8 years		1 to 10 yrs		2 to 10 yrs
Annualized volatility		147.1%		144.2%		201.4%
Dividend rate		0.00%		0.00%		0.00%

6. OIL AND GAS PROPERTY INTERESTS

	2014 (Cumulative)
	Peace River		Drowned		Total
Property acquisition and lease payments	$	2,502,876	$	37,347	$	2,540,223
Geological and geophysical		353,289		12,645		365,934
Project management		939,721		–		939,721
Drilling		3,205,440		–		3,205,440
Assaying and analysis		116,347		–		116,347
Asset retirement obligations		104,104		–		104,104
Camp and field supplies		37,987		–		37,987
Travel and accommodation		114,210		–		114,210
Total expenditures	$	7,373,974	$	49,992	$	7,423,966

F-14

6. OIL AND GAS PROPERTY INTERESTS continued

	2013 (Cumulative)
	Peace River		Drowned		Total
Property acquisition and lease payments	$	2,654,733	$	40,736	$	2,695,469
Geological and geophysical		328,727		13,792		342,518
Project management		880,202		–		880,202
Drilling		3,493,340		–		3,493,340
Assaying and analysis		93,762		–		93,762
Asset retirement obligations		113,550		–		113,550
Camp and field supplies		41,433		–		41,433
Travel and accommodation		124,573		–		124,573
Total expenditures	$	7,730,320	$	54,528	$	7,784,848

Peace River Property

The Company has entered into a series of leases in multiple transactions with the Province of Alberta in the Peace River area of Alberta, Canada (the “Peace River Property”). All of the leases were acquired through a public auction process that requires the Company to submit sealed bids for land packages being auctioned by the provincial government. Upon being notified that it has submitted the highest bid for a specific land parcel the Company immediately pays the government the bid price and enters into a formal lease with the government. All of the leases are for a 15 year term, require minimum annual lease payments, and grant the Company the right to explore for potential oil sands opportunities on the respective lease. The specific transactions entered into by the Company are as noted below.

Date	Number of Leases		Land Area (Hectares)		Annual Lease Payments
June 15, 2006		3		4,864	CDN $17,024 / USD $14,675
October 19, 2006		4		3,584	CDN $12,544 / USD $10,813
November 2, 2006		4		5,632	CDN $19,712 / USD $16,992
January 11, 2007		4		4,608	CDN $16,128 / USD $13,902
January 24, 2007		2		2,304	CDN $8,064 / USD $6,951
		17		20,992	CDN $73,472 / USD $63,332

Drowned Property

On September 7, 2005 the Company acquired a 100% interest in an Alberta oil sands lease (the “Drowned Property”). The rights to the Drowned Property were acquired for $20,635 plus fees and closing costs of $8,150 which were paid. The Property covers 512 hectares of land in the Drowned Area of the Wabasca oil sands in the West Athabasca area of Northern Alberta. The lease, which expires in October 2015, gives the Company the right to explore the Property covered by the lease. The Company’s acquisition of the lease includes an overriding 4% royalty agreement with the vendor. The royalty is to be paid on a well-to-well basis and is payable on all petroleum substances produced by any well on the Property. The Property is subject to an annual lease payment payable to the government of Alberta in the amount of CDN $1,792 (USD $1,545) until expiry on October 4, 2015. The Company can apply for continuation of the leases based on prior exploration and historical findings. The Government of Alberta will review each case on an individual basis, if approved the government will grant an extension, otherwise the lease will expire.

All of the Company’s leases for the Peace River and Drowned Properties are also subject to royalties payable to the government of Alberta. The royalties payable to the government of Alberta is in addition to the royalties payable to the vendor above. The royalty is calculated using a revenue-less-cost formula. In years prior to the recovery of the project’s capital investment, the royalty is 1% of gross revenue. Once the project costs have been recovered, the royalty is the greater of 1% of gross revenue or 25% of net revenue.

F-15

6. OIL AND GAS PROPERTY INTERESTS - continued

The following table sets forth the Company’s future minimum lease payments for both the Peace River and Drowned oil and gas properties for the years ending December 31:

Year	Future Minimum Lease Payments
2015	$	64,877
2016		63,332
2017		63,332
2018		63,332
2019		63,332
Thereafter		84,186
Total	$	402,391

7. ASSET RETIREMENT OBLIGATIONS

During 2007, the Company drilled four wells on its Peace River Property. Total future asset retirement obligations were estimated by management based on the Company’s working interest in its wells and facilities, estimated costs to remediate, reclaim and abandon the wells and facilities and the estimated timing of the costs to be incurred in future periods. The Company has estimated the net present value of its total asset retirement obligations to be approximately $138,048 at December 31, 2014 (2013 - $139,623), based on an undiscounted total future liability of $252,566 (CDN$293,000). These payments are expected to be incurred between 2015 and 2030. The Company used a credit adjusted discount rate of 10% per annum and an inflation rate of 2% to calculate the present value of the asset retirement obligation. Accretion expense of $10,545 (2013 – $10,487, 2012 - $7,500) has been recorded in the Statements of Operations and Comprehensive Loss at December 31, 2014.

8. RELATED PARTY TRANSACTIONS

Related party transactions not disclosed elsewhere in these financial statements include:

Consulting Fees

Mr. Daems does not bill the Company for his services as President; however, a related party by common director has a service agreement with the Company to assist with identification, acquisition and service of certain exploration style properties that fit the parameters of the Company’s acquisition plan. The Company recognized an expense of $45,032 in 2014 (2013 - $53,304, 2012 - $26,582) as consulting fees under the agreement.

9. SHARE CAPITAL

On August 6, 2012, the Company closed two private placements for a total of 1,250,000 units at $0.04 per unit for an aggregate total offering price of $50,000. Each unit consisted of one share of common stock of the Company and one Class A Warrant exercisable for one share of common stock at an exercise price of $0.06 for a period of four years commencing on August 6, 2013 and expiring on August 6, 2017.

On August 6, 2012, the Company closed a private placement for a total of 2,500,000 units at $0.04 per unit for a total offering price of $100,000. Each unit consisted of one share of common stock of the Company also with one Class A, one Class B and one Class C Warrant, each exercisable for one share of common stock at an exercise price of $0.10, $0.20 and $0.30 commencing on August 6, 2013, 2014 and 2015 and expiring on August 6, 2022.

F-16

9. SHARE CAPITAL continued

On August 20, 2012, the Company closed a private placement for a total of 625,000 units at $0.04 per unit for a total offering price of $25,000. Each unit consisted of one share of common stock of the Company and one Class A Warrant exercisable for one share of common stock at an exercise price of $0.06 for a period of four years commencing on August 20, 2013 and expiring on August 20, 2017.

On September 19, 2012, the Company closed a private placement for a total of 416,667 units at $0.06 per unit for a total offering price of $25,000. Each unit consisted of one share of common stock of the Company and one Class A Warrant exercisable for one share of common stock at an exercise price of $0.09 for a period of four years commencing on September 19, 2013 and expiring on September 19, 2017.

On October 26, 2012, the Company closed a private placement for a total of 440,000 units at $0.06 per unit for a total offering price of $26,400. Each unit consisted of one share of common stock of the Company and one Class A Warrant exercisable for one share of common stock at an exercise price of $0.09 for a period of four years commencing on October 26, 2013 and expiring on October 26, 2017

The Company classified the entire proceeds of $226,400 from private placements closed in 2012 as a derivative liability related to the warrants.

For the year ended December 31, 2013, the Company closed a series of private placements totaling 8,397,296 units at $0.08 to $0.24 per unit for total offering proceeds of $804,502. Each unit consisted of one share of common stock of the Company and one Class A Warrant exercisable for one share of common stock at an exercise price of $0.12 to $0.32 for a period of four years commencing one year after the placements closed.

On May 13, 2013 the Company closed a private placement totaling 1,250,000 units at $0.08 per unit for a total offering price of $100,000. Each unit consisted of one share of common stock and one Class A Warrant with an exercise price of $0.10, one Class B Warrant with an exercise price of $0.20 and one Class C Warrant with an exercise price of $0.30. Each warrant is exercisable for one share of common stock and expires on May 13, 2023.

On August 26, 2013 the Company closed a private placement totaling 812,500 units at $0.08 per unit for a total offering price of $65,000. Each unit consisted of one share of common stock, one Class A Warrant with an exercise price of $0.12 and one Class B Warrant with an exercise price of $0.18. Each warrant is exercisable for one share of common stock and expires on August 26, 2018

The Company classified the entire proceeds of $969,502 from private placements closed in 2013 as a derivative liability related to the warrants.

On December 11, 2013, 625,000 common share warrants were exercised at exercise prices of $0.06 for total proceeds of $37,500. Upon exercise, the fair value of this liability instrument at this date of $117,069 was re-classified from liability to additional paid in capital. See Note 5.

During the year ended December 31, 2014 the Company closed a series of private placements totaling 3,002,177 units at $0.09 to $0.12 per unit for total offering proceeds of $301,600. Each unit consisted of one share of common stock of the Company and one Class A Warrant exercisable for one share of common stock at an exercise price of $0.14 to $0.18 for a period of five years from the date of placement.

The Company classified the entire proceeds of $301,600 from these private placements as a derivative liability related to the warrants.

For the year ended December 31, 2014, 652,500 common share warrants were exercised at exercise prices of $0.09 to $0.15 for total proceeds of $69,600. Upon exercise, the fair value of these liability instruments of $110,049 was re-classified from liability to additional paid in capital. See Note 5.

F-17

9. SHARE CAPITAL – continued

Earnings per share

Basic income per common share is computed by dividing income available to the Company’s common stockholders by the weighted average number of common shares outstanding during the period. Diluted income per common share reflects the potential dilution that could occur from common share issuable through stock options and warrants. Diluted income per common share is computed similarly to basic income per common stock except that weighted average common stock is increased to include the potential issuance of dilutive common stock.

	2014			2013			2012
Net income (loss) for the year	$	(283,101	)	$	(2,798,169	)	$	(1,856,790	)

Weighted average common stock basic		87,191,251			80,057,824			71,340,773
Effect of options		–			–			–
Effect of warrants		–			–			–
Diluted		87,191,251			80,057,824			71,340,773

At December 31, 2014, 2013 and 2012, the effect of the Company’s outstanding options and warrants would have been anti-dilutive. Accordingly, only basic income per common share is presented for all years.

10. STOCK OPTION PLANS

In June 2006 the stockholders approved and the Company adopted its 2006 Stock Option Plan (“the 2006 Plan”). The 2006 Plan provides for the granting of up to 8,000,000 stock options to key employees, directors and consultants, of common shares of the Company. Under the 2006 Plan, the granting of incentive and non-qualified stock options, exercise prices and terms are determined by the Company's Option Committee, a committee designated to administer the 2006 Plan by the Board of Directors. For incentive options, the exercise price shall not be less than the fair market value of the Company's common stock on the grant date. (In the case of options granted to an employee who owns stock possessing more than 10% of the voting power of all classes of the Company's stock on the date of grant, the option price must not be less than 110% of the fair market value of common stock on the grant date.) Options granted are not to exceed terms beyond ten years (five years in the case of an incentive stock option granted to a holder of 10 percent of the Company's common stock).

Activity under the 2006 Plan is summarized as follows:

	Available for Grant			Options Outstanding			Weighted Average Exercise Price
Balance, December 31, 2011		6,100,000			600,000		$	1.14
Granted		(1,400,000	)		1,400,000			0.16
Cancelled		–			–			–
Balance, December 31, 2012		4,700,000			2,000,000			0.46
Granted		–			–			–
Forfeited		1,000,000			(1,000,000	)		0.17
Balance, December 31, 2013		5,700,000			1,000,000			0.73
Granted		(3,770,000	)		3,770,000			0.17
Forfeited		–			–			–
Balance, December 31, 2014		1,930,000			4,770,000		$	0.29

Balance exercisable, December 31, 2014					3,670,000		$	0.30

F-18

10. STOCK OPTION PLANS continued

The following table summarizes information concerning outstanding and exercisable common stock options under the 2006 Plan at December 31, 2014:

Range of Exercise Prices	Number of Options Outstanding	Remaining Contractual Life (in Years)	Weighted Average Exercise Price	Number of Options Currently Exercisable
$0.07	200,000	7.53	$0.07	200,000
$0.13	25,000	5.92	$0.13	25,000
$0.14	2,870,000	9.18	$0.14	2,870,000
$0.20	25,000	5.92	$0.20	25,000
$0.25	1,100,000	9.84	$0.25	-
$0.40	25,000	5.92	$0.40	25,000
$0.60	25,000	5.92	$0.60	25,000
$0.61	200,000	2.22	$0.61	200,000
$0.74	100,000	3.56	$0.74	100,000
$2.29	200,000	1.56	$2.29	200,000
	4,770,000			3,670,000

The aggregate intrinsic value of stock options outstanding at December 31, 2014 was $45,200 (2013 - $31,250, 2012 - $17,000) while the aggregate intrinsic value of stock options exercisable at December 31, 2014 was $45,200 (2013 - $23,250, 2012 - $Nil). No stock options were exercised in 2014, 2013, or 2012.

The following table summarizes information concerning unvested common stock options under the 2006 Plan at December 31, 2014:

	Number of Unvested Options			Weighted Average Exercise Price		Weighted Average Grant Date Fair Value

Unvested at December 31, 2011		50,000		$	0.13	$	0.37
Granted		1,400,000			0.16		0.07
Vested		(25,000	)		0.40		0.12

Unvested at December 31, 2012		1,425,000			0.17		0.07
Vested		(225,000	)		0.13		0.07
Forfeited		(100,000	)		0.14		0.07

Unvested at December 31, 2013		200,000			0.14		0.11
Granted		3,770,000			0.17		0.17
Vested		(2,870,000	)		0.13		0.14

Unvested at December 31, 2014		1,100,000		$	0.25	$	0.23

As of December 31, 2014, there was $133,819 (2013 – $12,016, 2012 - $115,900) of total unrecognized compensation cost related to all unvested options granted and outstanding. This unrecognized compensation cost is expected to be recognized over a weighted average period of approximately 2 years.

During the year ended December 31, 2014, the Company recorded consulting fees of $421,923 (2013 – $80,080; 2012 – $40,826) in the statement of operations related to stock options granted to non-employees during the year.

The Company issues new shares when options are exercised.

F-19

11. WARRANTS

Issued	Warrants			Weighted Average Exercise Price
Balance, December 31, 2011		16,413,885		$	0.23
Warrants issued		10,231,667			0.10
Warrants expired		(3,395,555	)		0.23
Balance, December 31, 2012		23,249,997			0.27
Warrants issued		13,772,296			0.16
Warrants exercised		(625,000	)		0.06
Warrants expired		(500,000	)		2.19
Balance, December 31, 2013		35,897,293			0.20
Warrants issued		3,002,177			0.15
Warrants exercised		(652,500	)		0.08
Warrants expired		(1,900,000	)		0.20
Balance, December 31, 2014		36,346,970		$	0.20

The following table lists the common share warrants outstanding at December 31, 2014. Each warrant is exchangeable for one common share.

Number Outstanding	Number Vested	Average Exercise Price	Expiry Year *
7,668,330	7,668,330	$0.20	2016
4,616,667	4,616,667	$0.36	2017
9,809,796	9,809,796	$0.14	2018
3,002,177	-	$0.15	2019
7,500,000	7,500,000	$0.20	2022
3,750,000	3,750,000	$0.20	2023
36,346,970	33,344,793

* On October 31, 2014 the Board of Directors resolved to offer an extension to the exercise period for certain warrants for a period of up to 2 years from their original expiration date. The warrant holders who completed the warrant extension agreement had the expiration date extended as specified in the agreement. Warrant holders that did not elect to have their warrants extended were allowed to expire. There was no additional cost associated with the extension as the change in the value of the warrants is recognized through the change in the fair value of the derivative liability on the face of the statements of operations.

12. INCOME TAXES

The tax effects of temporary differences that give rise to the Company’s deferred tax assets are as follows:

	2014			2013
Deferred tax assets (liabilities)
Net operating loss carry-forwards	$	956,000		$	1,124,700
Capital losses		5,000			5,000
Office equipment		12,500			12,500
Oil and gas properties		2,133,900			2,001,600
Asset retirement obligation		63,000			52,300
		3,170,400			3,196,100
Valuation allowance		(3,170,400	)		(3,196,100	)
Net deferred tax asset	$	–		$	–

F-20

12. INCOME TAXES continued

Upon continuation to Canada in 2004, all losses carried forward at that time expired. As of December 31, 2014, the Company had available to offset future taxable income and net Canadian operating loss carry-forwards of approximately $3.8 million. The carry-forwards began expiring in 2014 and unless utilized will continue to expire. The Company also has approximately $8.0 million in Canadian oil and gas dedication pools that can be used to offset income of future periods. The amount of oil and gas dedication pools available for deduction in any year may be limited to 30% of the amount available.

The Company evaluates its valuation allowance requirements based on projected future operations. When circumstances change and this causes a change in management's judgment about the recoverability of deferred tax assets, the impact of the change on the valuation allowance is reflected in current income. During the years ended December 31, 2014, 2013 and 2012, changes in valuation allowance was ($25,700), $126,500 and $54,500, respectively.

The (benefit) provision for income taxes differs from the amount of income tax determined by applying the applicable Canadian statutory federal income tax rate to pre-tax loss as a result of the following differences:

	2014			2013			2012
Statutory federal income tax rate		(25	%)		(23	%)		(25	%)
Change in valuation allowance		1	%		(9	%)		(5	%)
Non-deductible stock-based compensation		(149	%)		3	%		1	%
Non-deductible change in fair value of derivative liability		165	%		32	%		30	%
Non-deductible accretion expense		4	%		–	%		–	%
Effect of foreign exchange		2	%		(1	%)		1	%
Effect of change in income tax rate		2	%		(2	%)		(2	%)
		–	%		–	%		–	%

The Company has evaluated its tax positions for the years ended December 31, 2014, 2013 and 2012 and determined that it has no uncertain tax positions requiring financial statement recognition.

Under ASC 740-10-25, the impact of an uncertain income tax position on income tax expense must be recognized at the largest amount that is more-likely-than-not to be sustained. An uncertain income tax position will not be recognized if it has 50% or less likelihood of being sustained.

We accrue interest and penalties on our uncertain tax positions as a component of our provision for income taxes. There was no amount of interest and penalties recognized as an expense during 2014, 2013 or 2012.

Our income tax returns are generally considered closed to examination when we file a notice of determination with the taxing authority. No such notice has been filed to date.

13. COMMITMENTS AND CONTINGENCIES

Environmental Matters

The Company is engaged in oil and gas exploration and may become subject to certain liabilities as they relate to environmental cleanup of sites or other environmental restoration procedures as they relate to the exploration of oil and gas. Should it be determined that a liability exists with respect to any environmental clean up or restoration, the liability to cure such a violation could fall upon the Company. No claim has been made, nor is the Company aware of any liability, which it may have, as it relates to any environmental clean-up, restoration or the violation of any rules or regulations relating thereto. Liabilities for expenditures are recorded when environmental assessment and/or remediation is probable and the costs can be reasonably estimated.

F-21

14. SUBSEQUENT EVENTS

Subsequent the year end the Company closed private placements for a total of 1,811,000 units for an aggregate total offering of $169,990. Each unit consisted of one share of common stock of the Company and one Class A Warrant exercisable beginning on the one year anniversary date of the placement, for one share of common stock for a period of four years and expiring in 2019.

In March 2015 the Company advanced an additional $17,047 (Canadian $21,500) to a related party under the short term note agreements referenced in Note 4 to these financial statements.

F-22

EXHIBIT 1.3

Adopted by the Board of Directors of

Strata Oil & Gas Inc. (the “Company”)

on August 3, 2006

STRATA OIL & GAS INC.

AUDIT COMMITTEE OF THE BOARD

Mandate

The mandate of the committee is to assist the Board of Directors in fulfilling its oversight responsibilities. The audit committee will review the financial reporting process, the system of internal control, the audit process, and the Company’s process for monitoring compliance with laws and regulations. The committee will maintain effective working relationships with the Board, management and external auditor. To effectively perform his or her role, each committee member will obtain an understanding of the detailed responsibilities of committee membership as well as the company’s business, operations and risks. The Committee shall have the authority to select and retain staff and experts as deemed appropriate to fulfill its mandate.

Structure

The committee will be comprised of at least three Directors, all of whom will be unrelated. The Board will appoint the committee members and the committee chair annually. All committee members shall be financially literate and at least one member should have accounting or related financial expertise.

Meetings

The Committee shall convene at such times and places designated by the chair, or when requested by a Director, an officer of the company or the external auditor. The committee shall meet once a quarter to review the financial statements and to discuss any other matter consistent with the committee’s mandate.

Notice shall be given of the time and place of each meeting in writing, facsimile or e-mail to each committee member at least 24 hours prior to the proposed time, unless advance notice is waived by the committee member.

A meeting shall be duly convened if a majority of the members are present. Members may participate by telephone or other communications facility as permit all persons participating in the meeting to communicate with each other.

In the absence of the chair, the participating members shall choose one of the members to chair the meeting.

The committee may request any officer or employee of the company, the outside counsel or the external auditor to attend a meeting of the committee or to meet with members of the committee or its advisors.

Roles and Responsibilities

External Auditor

Meet regularly with external auditor.

Review the performance of the external auditors and recommend to the Board of Directors the appointment or discharge of the external auditor.

Review and assess the independence of the external auditors by reviewing the non-audit services provided and the auditors' assertion of their independence in accordance with professional standards.

Approve all significant non-audit work to be performed by the external auditor. The committee will establish thresholds above which all non-audit engagements are to be approved by the committee or a designated committee member.

Review and approve the external auditor's proposed audit scope, approach, and fees.

Monitor the external auditor’s progress against the audit plan throughout the year.

Receive and consider all significant findings and recommendations made by the external auditor on a timely basis.

Ensure that the external auditor keeps the audit committee informed about fraud, illegal acts, deficiencies in internal control, and certain other matters as requested.

Ensure that the external auditor is aware that it is accountable to the committee and to the Board of Directors as representatives of the shareholders, and that no restrictions are being placed on the auditor’s work.

Recommend to the Board of Directors the external auditor to be nominated for the purposes of issuing an auditors report or performing other audit, review or attest services.

Recommend to the Board of Directors the compensation of the external auditor.

Financial Reporting

General

Review significant accounting and reporting issues, including recent professional and regulatory pronouncements, and understand their impact on the financial statements.

Review with management and the external auditor any significant risks and exposures and the plans to minimize such risks.

Ask the external auditor if significant accounting estimates, judgements, accounting policies and financial disclosure practices determined by management are an appropriate, including their assessment of the quality of the company’s accounting principles and financial disclosure.

Annual Financial Statements

Review the annual financial statements and determine whether they are complete and consistent with the information known to committee members, and assess whether the financial statements reflect appropriate accounting principles.

Review the accounting and financial statement disclosure focusing on areas requiring judgement and on complex or unusual transactions.

Meet with management and the external auditor to review the financial statements and the results of the audit.

Consider management's handling of proposed audit adjustments identified by the external auditor.

Review the Management Discussion and Analysis (“MD&A”) and other sections of the 20-F before its release and consider whether the information is adequate and consistent with members' knowledge about the company and its operations.

Recommend to the Board of Directors for approval the annual financial statements and the MD&A.

Interim Financial Statements

Review how management developed and summarized interim financial information.

Meet with management either telephonically or in person, to review the interim financial statements. (This may be done by the committee chair or the entire committee.)

To gain insight into the fairness of the financial statements and disclosures, review quarterly with management whether:

Actual financial results for the interim period varied significantly from budgeted or projected results;

Changes in financial ratios and relationships in the interim financial statements are consistent with changes in the company's operations and financing practices;

Generally accepted accounting principles have been consistently applied;

There are any actual or proposed changes in accounting or financial reporting practices;

There are any significant or unusual events or transactions;

The company's financial and operating controls are functioning effectively;

The company has complied with the terms of loan agreements or security indentures; and

The interim financial statements contain adequate and appropriate disclosures.

Review the MD&A for the interim period before its release and consider whether the information is adequate and consistent with members' knowledge about the company and its operations.

Recommend to the Board of Directors for approval of the interim financial statements and the MD&A.

Compliance with Laws and Regulations

Review the effectiveness of the system for monitoring compliance with laws and regulations and the results of management's investigation and follow-up (including disciplinary action) on any fraudulent acts or accounting irregularities.

Periodically obtain updates from management regarding compliance.

Be satisfied that all regulatory compliance matters have been considered in the preparation of the financial statements.

Review the findings of any examinations by regulatory agencies.

Internal Control

Evaluate the adequacy and effectiveness of the accounting and internal control policies of the company through inquiry and discussion with the external auditor and with management.

Evaluate whether management is setting the appropriate tone by communicating the importance of internal control and ensuring that all individuals possess an understanding of their roles and responsibilities.

Gain an understanding of whether internal control recommendations made by the external auditor have been implemented by management.

Other Responsibilities

Review, with the company's counsel, any legal and regulatory matters that could have a significant impact on the company's financial statements.

Review any prospectus, 20-F or other similar documents, including the financial information contained therein.

Discuss with management the policies and procedures in effect for managing the principal risks of the company.

Review the policies and procedures in effect for considering officers' expenses and perquisites.

If necessary, institute special investigations and, if appropriate, hire special counsel or experts to assist.

Perform other oversight functions as requested by the full Board.

Review and update the charter as necessary and receive approval of changes from the Board.

Ensure that adequate procedures are in place for the receipt, retention and treatment of:

Complaints regarding accounting, financial disclosure, internal controls or auditing matters; and

Confidential, anonymous submission by employees regarding questionable accounting, auditing and financial reporting and disclosure matters.

Review the appointment of any new Financial Officers and any other key financial executives involved in the financial reporting process.

Review and approve policies related to the hiring of partners and employees of the external auditor.

Review the annual and interim earnings press releases before the public disclosure of such information.

Satisfy itself that adequate procedures are in place for the review of the issuer’s public disclosure of financial information.

Reporting Responsibilities

Regularly update the Board of Directors on committee activities and make appropriate recommendations.

EXHIBIT 12.1

CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER

PURSUANT TO SECTION 302(a) OF THE SARBANES-OXLEY ACT OF 2002

I, Ron Daems, certify that:

1. I have reviewed this Annual Report on Form 20-F of Strata Oil & Gas Inc. (the “Company”);

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 Company as of, and for, the periods presented in this report;

4. The Company’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 company 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 company, 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 Company’s disclosure controls and procedures and presented in this report my 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 Company’s internal control over financial reporting that occurred during the period covered by the Annual Report that has materially affected, or is reasonably likely to materially affect, the Company’s internal control over financial reporting; and

5. As the Company's only certifying officer, I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the Company’s auditors and the audit committee of the Company’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 Company’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 Company’s internal control over financial reporting.

Dated: April 29, 2015

By:	/s/ Ron Daems
Name:	Ron Daems
Title:	President, Chief Executive Officer, Secretary, and Director

EXHIBIT 12.2

CERTIFICATION OF PRINCIPAL FINANCIAL OFFICER

PURSUANT TO SECTION 302(a) OF THE SARBANES-OXLEY ACT OF 2002

I, Ron Daems, certify that:

1. I have reviewed this Annual Report on Form 20-F of Strata Oil & Gas Inc. (the “Company”);

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

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

Dated: April 29, 2015

By:	/s/ Ron Daems
Name:	Ron Daems
Title:	President, Chief Executive Officer, Secretary, and Director

EXHIBIT 13.1

CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER PURSUANT TO

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

The undersigned, Ron Daems, certifies, under the standards set forth and solely for the purposes of 18 U.S.C. 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that the Annual Report on Form 20-F of Strata Oil & Gas Inc. (the “Company”) for the fiscal year ended December 31, 2014 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 and that information contained in the Form 20-F fairly presents, in all material respects, the financial condition and results of operations of the Company.

Dated: April 29, 2015

By:	/s/ Ron Daems
Name:	Ron Daems
Title:	President, Chief Executive Officer, Secretary, and Director

EXHIBIT 13.2

CERTIFICATION OF PRINCIPAL FINANCIAL OFFICER PURSUANT TO

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

Dated: April 29, 2015

By:	/s/ Ron Daems
Name:	Ron Daems
Title:	President, Chief Executive Officer, Secretary, and Director

EXHIBIT 14.1

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We consent to the incorporation by reference in the Registration Statement on Form S-8 (File No. 333-82579) of our report dated April 29, 2015, on our audits of the balance sheets of Strata Oil & Gas Inc. ("the Company") as of December 31, 2014 and 2013, and the related statements of operations and comprehensive income (loss), changes in stockholders' equity (deficiency), and cash flows for the years then ended. Our report contains an explanatory paragraph regarding the Company’s ability to continue as a going concern.

/S/ PETERSON SULLIVAN LLP

Seattle, Washington

April 29, 2015

Strata Power (PK) (USOTC:SPOWF)
Historical Stock Chart
Von Nov 2024 bis Dez 2024

Click Here for more Strata Power (PK) Charts.

Strata Power (PK) (USOTC:SPOWF)
Historical Stock Chart
Von Dez 2023 bis Dez 2024

Marktdaten

News

Werkzeuge

Märkte

Entdecken

Hot Features

Follow Feed

Optionen-Flow

Watchlist

SPOWF Strata Power Corporation (PK)

News Strata Oil & Gas, Inc.

Kürzlich von Ihnen besucht

Unternehmen

Geschäft

Popular

App herunterladen

Trends

Toplisten

Marktdaten

News

Werkzeuge

Märkte

Entdecken

Hot Features

Follow Feed

Optionen-Flow

Watchlist

SPOWF Strata Power Corporation (PK)

News Strata Oil & Gas, Inc.

Kürzlich von Ihnen besucht

Unternehmen

Geschäft

Popular

App herunterladen