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

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 20-F/A

Amendment No. 2

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, 2016

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 14,215,016 shares outstanding at December 31, 2016 and 14,853,454 as of January 12, 2018. 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 ☐ No ☒

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 ☒ No ☐

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 ☒ No ☐

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 ☒ No ☐

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

Large accelerated filer ☐	Accelerated filer ☐
Non-accelerated filer ☒	Emerging growth company ☐

If an emerging growth company that prepares its financial statements in accordance with U.S. GAAP, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards † provided pursuant to Section 13(a) of the Exchange Act. ☐

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

U.S. GAAP ☒

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

Other ☐

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

Explanatory Note

The purpose of this Amendment No. 2 to Form 20-F for the year ended December 31, 2016, filed with the Securities and Exchange Commission on January 16, 2018 (the “Form 20-F”), is solely to include the audit report.

No other changes have been made to the Form 20-F. This Amendment No. 2 to the Form 20-F speaks as of the original filing date of the Form 20-F and does not modify or update in any way disclosures made in the original Form 20-F, other than the updated Auditor’s Report.

STRATA OIL & GAS INC.

FORM 20-F ANNUAL REPORT 2016

TABLE OF CONTENTS

Oil and Gas Glossary
Introduction

Part I

Item 1.	Identity of Directors, Senior Management and Advisers	3
Item 2.	Offer Statistics and Expected Timetable	3
Item 3.	Key Information	3
Item 4.	Information on the Company	10
Item 4A.	Unresolved Staff Comments	15
Item 5.	Operating and Financial Review and Prospects	15
Item 6.	Directors, Senior Management and Employees	21
Item 7.	Major Shareholders and Related Party Transactions	23
Item 8.	Financial Information	24
Item 9.	The Offer and Listing	25
Item 10.	Additional Information	26
Item 11.	Quantitative and Qualitative Disclosures About Market Risk	31
Item 12.	Description of Securities Other Than Equity Securities	31


Part II

Item 13.	Defaults, Dividend Arrearages and Delinquencies	32
Item 14.	Material Modifications to the Rights of Security Holders and Use of Proceeds	32
Item 15.	Controls and Procedures	32
Item 16.	Reserved
Item 16A.	Audit Committee Financial Expert	33
Item 16B.	Code of Ethics	34
Item 16C.	Principal Accountant Fees and Services	34
Item 16D.	Exemptions from the Listing Standards for Audit Committees	35
Item 16E.	Purchases of Equity Securities by the Issuer and Affiliated Purchasers	35
Item 16F.	Change in Registrants Certifying Accountant	35
Item 16G.	Corporate Governance	35
Item 16H.	Mine Health and Safety, Conflict Minerals and Government Payments	35


Part III

Item 17.	Financial Statements	35
Item 18.	Financial Statements	35
Item 19.	Exhibits	36

Signature Page		37

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.”

iii

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, 2016, 2015, 2014, 2013 and 2012.

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,
	2016			2015		2014			2013			2012
Revenue	$	–		$	–	$	–		$	–		$	–
Operating Expenses		7,919,352			283,731		753,287			574,609			241,995
Other income (expense), net		586,878			3,037,324		470,186			(2,223,559	)		(1,614,795	)
Net income (loss)	$	(7,332,474	)		2,753,593		(283,101	)	$	(2,798,169	)	$	(1,856,790	)

Basic income (loss) per common share:	$	(0.56	)	$	0.30	$	(0.03	)	$	(0.40	)	$	(0.30	)
Diluted income (loss) per common share:	$	(0.56	)		0.30		(0.03	)		N/A		$	N/A
Basic weighted average number of common shares outstanding		13,035,203			9,115,416		8,719,125			8,005,782			7,134,077
Diluted weighted average number of common shares outstanding		13,035,203			9,161,527		9,161,527			N/A			N/A

BALANCE SHEET DATA

(in U.S. Dollars)

	Strata Oil & Gas Inc.
	December 31,
	2016			2015			2014			2013		2012

Cash and cash equivalents	$	7,881		$	2,541		$	118,873		$	440,612	$	134,125
Other current assets		3,025			1,164			176,806			72,199		5,222
Reclamation deposits		121,391			116,806			133,745			121,870		123,634
Oil and gas property interests		–			6,237,026			7,423,966			7,784,848		8,195,885
Total assets		132,297			6,574,998			7,853,390			8,419,529		8,458,866
Current liabilities		971,363			1,175,810			4,564,235			5,180,432		2,377,418
Asset retirement obligations		138,728			128,301			138,049			139,623		138,129
Additional paid-in capital		22,919,431			21,975,988			21,905,643			21,304,071		21,069,422
(Accumulated deficit) retained earnings		(23,525,737	)		(16,193,263	)		(18,946,856	)		(18,663,755		(15,865,586	)
Accumulated other comprehensive income		(371,488	)		(533,352	)		192,319			459,158		739,483
Total liabilities and stockholders’ equity		132,297			6,574,998			7,853,390			8,419,529		8,458,866

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/daily-exchange-rates-lookup/ “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, 2016, 2015, 2014, 2013 and 2012, and the average rates for the period and the range of high and low rates for the period. The data for March 2017 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, 2016 was CDN $1.34 per U.S. $1.00.

The exchange rate as of January 15, 2017 was CDN $1.25 per U.S. $1.00.

Exchange Rates for Canadian Versus U.S. Dollars

(High/low rates for latest six months)

	High		Low
March, 2017		1.35		1.33
February, 2017		1.32		1.31
January, 2017		1.34		1.30
December, 2016		1.33		1.31
November, 2016		1.36		1.34
October 2016		1.34		1.31

Exchange Rates for Canadian Versus U.S. Dollars

		Average ($)
For the twelve months ended December 31, 2016		1.32
For the twelve months ended December 31, 2015		1.28
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

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 Trevor Newton, our CEO and President. The loss of Mr. Newton, 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 Trevor Newton, 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. Newton 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. Newton.

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 the following:

	·	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 effect 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, 2016 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 $23,525,737 as of December 31, 2016. 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 project regions in the Peace River region of Alberta, Canada consisting of oil sands lands, either acquired from the Government of Alberta or from third parties. 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. 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 revenue, we will have to raise additional funds through loans from existing shareholders, the sale of our equity securities or a 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 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 the time necessary to assist with the operations of the Company as necessary.

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 62 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 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 oil sands region in Northern Alberta, Canada.

The Company is currently engaged in the acquisition, exploration and if warranted and feasible development of heavy oil projects in the Peace River oil sands region. However, there is no assurance that a commercially viable oil project will be developed on any of its land holdings. Further analysis and testing is required before a final evaluation as to the economic and technical feasibility of the projects is determined.

As of December 31, 2016, the Company currently has interests in oil sands properties located in the Peace River oil sands region of Northern Alberta, Canada consisting of 62 leases covering 60,662 hectares in the Peace River oil sands region.

Material Effects of Government Regulation

The Crown owns and controls the mineral and hydrocarbon rights on Alberta lands and therefore the development, production and sale of oil in Alberta is subject to the laws and regulations of the Crown. The Crown makes available these rights on a lease basis and therefore, the oil sands leases held by the Company are on lands which are owned by the Crown and controlled by its agency, the Alberta Energy Regulator (AER). In order to maintain its oil sands leases, the Company must make significant expenditures on an annual basis to the Crown and also comply with its regulations. Matters subject to regulation include but are not limited to:

	·	location and density of wells
	·	obtaining permits for drilling and production
	·	accounting for and payment of royalties on production to the Crown
	·	transportation of oil
	·	operation of wells
	·	reporting of technical details to the Crown
	·	taxation

Under the Crown’s laws and regulations, the Company 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 could result in the suspension or termination of our operations and subject us to penalties. Moreover, these laws and regulations could change in ways that substantially affect our costs. Accordingly, any liabilities, penalties, suspensions, terminations or regulatory changes could have a material adverse effect 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 changes in the weather. If exploration is pursued during certain seasons of the year, the Company may incur additional costs to address issues relating to weather.

Shortages or an increase in the cost of operational services including drilling rig services, 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 operations may increase, which may lead to increases in associated costs, including those related to operational services. Increased drilling activity in these areas may also decrease the availability of operational services. We do not have any contracts with providers of operational services and therefore we may not be able to obtain these services when we need them. Therefore, our operational costs may increase and necessary equipment and services may not be available to us at current prices.

COMPETITION

The oil industry is intensely competitive and subject to rapid change. We compete with many exploration and production companies which have significantly greater personnel, financial, managerial and technical resources which impacts our ability to compete successfully in the industry.

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 62 oil sands leases covering 60,672 hectares in the Peace River oil sands region of northern Alberta, Canada.

Oil Sands Background

“Oil Sands” refers to either unconsolidated, bitumen-saturated sands or bitumen-saturated carbonate-rock. Bitumen 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 in the way lighter oil is most often produced. The oil sands in Alberta are contained in three major areas in Alberta.

According to the Alberta Energy Regulator (AER), Alberta's oil sands are the third-largest proven crude oil reserve in the world, with total proven reserves of 166 billion barrels, and total recent production of up to 2.3 million barrels per day.

These deposits contain a significant amount of oil but only in recent decades has commercial production become economic. Extraction of oil from oil sands requires the input of significant amounts of thermal energy or other technology. There are two main types of oil sands production methods: surface mining and in-situ. Surface mining is accomplished using an open pit operation whereby the oil sands are excavated and trucked to a processing facility. For oil sands reservoirs too deep to support surface mining, a technique known as in-situ recovery is utilized. In-situ production recovers the oil through a well, and utilizes thermal energy or other technologies to reduce the viscosity of the bitumen to allow it to flow to the well bore. There are some oil sands reservoirs where primary or “cold” production is possible. The oil in these reservoirs is light enough to flow to the well without thermal treatment, utilizing either vertical or horizontal wells.

Carboniferous Oil Sands

Carbonate oil sands, or carbonate-hosted bitumen, are unconventional resources that remain almost untapped. While much is known about Alberta’s vast sands-hosted bitumen resources, less is understood about a bitumen resource of similar magnitude which is hosted in carbonate rock directly beneath the sands. According to a report by Petroleum Technology Alliance Canada (PTAC), 26% of Alberta’s bitumen resources are contained in carbonate rather than sand formations. They are located in a roughly triangular 70,000 square-kilometer area of Alberta informally known as the Carbonate Triangle. The basic difference between sands and carbonates is that the former is bitumen mixed with unconsolidated sand, which can be either mined or produced from wells, whereas the latter is bitumen in carbonate rock. Currently, only pilot production of carbonate-hosted bitumen has taken place.

The Company has focused a portion of its efforts on the exploration and development of carbonate-hosted bitumen rather than just focusing on sand-hosted bitumen. The Company believes Alberta’s carbonate-hosted bitumen reservoirs represent an enormous and relatively untapped resource. The optimal means for producing bitumen from carbonates is still being studied, and there is unlikely to be a single Alberta-wide strategy for production. Cold production may be possible in some areas although in most cases production will require an in-situ treatment. Various technologies have been tested including similar technologies to those employed in the oil sands (cyclic steam, SAGD, and solvents.). There are several techniques which may prove to be effective. The Company is in the process of determining the most efficient means of producing bitumen from our projects.

Planned Work by the Company for 2017

The Company plans to continue focusing its resources on the analysis and development of its Peace River oil sands properties.

PEACE RIVER OIL SANDS LEASES

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 Properties”). Some 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 Crown the bid price and enters into a formal lease agreement. The bid price includes the first year’s minimum annual lease payments. The remainder of the leases were acquired by third parties, however all the Company’s leases are leased directly with the Crown.

The Peace River Properties consist of a total of 60,672 hectares of land in a region of northern Alberta known as the Peace River oil sands region. The leases are subject to royalties payable to the Government of Alberta. Alberta's 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 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 Properties are located in the Peace River oil sands region in Alberta approximately 40 to 50 kilometers away from the town of Peace River, in both the Cadotte Lake area and also the Reno area.

Peace River Projects

The Peace River properties (hereinafter referred to as “Cadotte West”, “Cadotte Central”, “Cadotte East”, the “Cadotte Leases” and the “Reno Leases”) are comprised of 62 oil sands leases with the Government of the Province of Alberta, Canada. All of the leases are for an initial 15-year term (and may then be converted to non-expiring leases) and require minimum annual lease payments to the Crown. Each lease grants the Company the right to explore for, develop and produce hydrocarbons from the geological formations described in each 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 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 and heavy oil resources contained in the Debolt/Elkton carbonate Carboniferous Formation and the Bluesky/Gething clastic Cretaceous Formation in the Cadotte and Reno areas.

The nature of the geology of the carbonate sequence in the Cadotte 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 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 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 may be the result of post-depositional tectonic events and may not reflect the original orientation of the accumulation of sediment. The Carboniferous sequence of the Rundle assemblage is believed to have 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 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 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 sands deposits near Fort McMurray in the Athabasca region of Alberta.

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. 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 Cadotte and Reno areas. 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 Cadotte area are drilled at an average spacing of one well per section. However, not all the 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 Cadotte lease blocks. The well log data from these wells is the primary source of information on the leases available for Strata’s evaluations but this is 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 and Cadotte West

The Company completed the drilling of its first four wells in the winter drilling season of 2006 – 2007, and engaged Norwest Corporation (“Norwest”) of Calgary, Alberta, Canada to assist Strata with the planning and undertaking of its exploration of the Cadotte leases. Subsequently, Strata completed the following technical reports relating to these leases:

Evaluation of In-Place Bitumen Resources – Cadotte Central Leases (August 16, 2007) [Norwest]

Preliminary Feasibility Study of the Cadotte Central Leases (February 29, 2008) [Norwest Questa]

Pilot Projects: Carbonate-Hosted Bitumen Deposits in Alberta (July 17, 2008 [Norwest]

Cadotte Central Resource Reclassification (Upgrade) (April 28, 2010) [Norwest]

Evaluation of Bitumen Resources Cadotte Central and West Leases (May 10, 2013) [Norwest]

These studies were 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 (“COGEH”) at the time they were authored. However since that time, COGEH standards have been modified and therefore Strata is no longer permitted to publicize the contents of these reports under Canadian Securities Regulations.

Subsequent to these studies, Strata completed additional analyses including a study entitled “ Debolt Core Description and Interpretation ” by Dr. Hans G. Machel, and also a seismic study by Norwest entitled “ Seismic Study of Cadotte Leases ” to evaluate the Cadotte West property for heavy-oil recovery using cold production.

The latter study utilized existing well and seismic data and focused on different physical properties and technical aspects related to the identification of pools and fields on Strata’s Cadotte West 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 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 late 2014, Strata 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 included 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. Due to the oil market, the Company has not carried out its drilling program. At any point, the Company may update and resubmit its OSE plan to the Crown.

Planned Work by the Company for 2017

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.

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, 2016, 2015 and 2014. 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:

	2016			2015		2014
Operating expenses	$	7,919,352		$	283,731	$	(753,287	)
Other income	$	586,878			3,037,324	$	470,186
Net income / (loss)	$	(7,332,474	)	$	2,753,593	$	(283,101	)
Earnings per share from continuing operations, basic	$	(0.56	)	$	0.30	$	(0.03	)
Earnings per share from continuing operations, diluted	$	(0.56	)	$	0.30	$	(0.03	)
Basic weighted average common shares outstanding		13,035,203			9,115,416		8,719,125
Diluted weighted average common shares outstanding		13,035,203			9,161,527		8,719,125

REVENUES

The Company did not earn any revenue for the year ended December 31, 2016, 2015 and 2014. 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.

Year ended December 31, 2016 compared to the year ended December 31, 2015

RESULTS OF OPERATIONS

In 2016, the Company focused its efforts on the acquisition of a portfolio of oil sands leases in the Cadotte and Reno areas of the Peace River. The leases totaled 39,680 hectares, more than doubling the Company’s holdings.

The Reno leases are contiguous with Baytex Energy’s lease block, an area that hosts extensive primary production of heavy oil. The other major contiguous lease blocks are held by Koch Exploration.

The Cadotte leases we acquired are contiguous with our existing Cadotte holdings or nearby. The area hosts extensive thermal production of bitumen, including CNRL’s adjacent Peace River Thermal Complex.

The Company has thoroughly analyzed the entire property portfolio and prioritized the highest potential primary production targets.

During the years ended December 31, 2016 and 2015, we had net loss of ($7,332,474) and net income of $2,753,593, respectively, for a decrease of $10,086,067. The decrease in net income is due to an increase in non-cash charges of $10,252,894 offset by a decrease in expenses of $166,827. The change in non-cash charges consisted of an increase in oil and gas impairment of $7,831,570 and a decrease in the change in fair value of derivative liabilities of $2,421,325.

For the years ended December 31, 2016 and 2015, we recognized an impairment expense of $7,831,570 and $nil, respectively. As of December 31, 2016, management determined to fully impair its unproved oil and gas properties. We did not recognize an impairment in 2015.

For the years ended December 31, 2016 and 2015, we recorded a gain on the change in fair value of derivative liability of $584,880 and $3,006,205, respectively. 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.

For the years ended December 31, 2016 and 2015, we recognized operating expenses, excluding the oil and gas impairment charge, of $87,783 and $283,731, respectively, for an approximate decrease of $196,000. The decrease in operating expenses is primarily due to an approximate $123,000 decrease in consulting fees as consulting fees during 2016 were capitalized as exploration costs as part of oil and gas properties. Operating expenses also decreased an approximate $45,000 due to no losses recognized in the year ended December 31, 2016 relating to the disposal of oil and gas properties. Further, operating expenses decreased an approximate $12,000 and $7,000 due to a decrease in office expenses and asset retirement accretion expense, respectively, due to less activity during the year from the general slow-down in the oil and gas industry.

INTEREST AND OTHER INCOME (EXPENSE)

Included in other income (expense) for the year ended December 31, 2016, is a gain of $584,880 relating to the change in fair value of derivative liability resulting from a decrease in the fair value of the derivative liability off-set by the issuance of common stock warrants. The decrease in derivative liability was the result of a decrease in the Company’s stock price at December 31, 2016 compared to 2015. See Note 5 of the Financial Statements for more on the change in the derivative liability. The Company determined the fair value of the derivative liability to be $779,796 as of December 31, 2016 based on an acceptable valuation model.

B. Liquidity and Capital Resources

(in U.S. dollars)	As at December 31,
	2016			2015			2014
Cash and cash equivalents	$	7,881		$	2,541		$	118,873
Working capital (deficit)		(960,457	)		(1,172,105	)		(4,268,555	)
Net cash provided by (used in)
Operating activities		(18,024	)		(214,127	)		(247,614	)
Investing activities		(199,121	)		(120,949	)		(425,987	)
Financing activities		223,000			248,114			371,200

As of December 31, 2016, we had $7,881 in cash, an increase of $5,340 from December 31, 2015. The increase in cash is primarily due to a decrease in operating expenses offset by an increase in investing activities from the acquisition of additional oil and gas properties. Management estimates that the Company will require approximately $525,000 to fund planned operations for the next twelve months. Therefore, current cash on hand is not sufficient to fund planned operations for 2017. 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 2017 our capital requirements will mostly be associated with the maintenance of our lease payments to the Crown. 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, 2016 was $18,024 compared to $214,127 in 2015. The decrease in cash used in operating activities was primarily due to a decrease in operating expense during 2016 compared to 2015.

Cash used in investing activities during the year ended December 31, 2016 was $199,121 compared to cash used in investing of $120,949 in 2015. During 2016, the Company acquired an additional 45 oil and gas properties leases for a total of 45,680 hectares in Northern Alberta, Canada.

The Company generated net cash inflows from financing activities of $223,000 compared to $248,114 in 2015 The Company raised $223,000 in funds from a series of private placements during 2016. See Note 9 to the financial statements for more information.

We had cash of $7,881 as of December 31, 2016. We anticipate that we will incur the following expenditures through the end of our next fiscal year:

	·	$225,000 in connection with property lease payments and follow up analysis on the Company’s oil sands properties;

	·	$300,000 for operating expenses, including working capital, consulting fees, general and administrative, professional, legal and accounting expenses;

Year ended December 31, 2015 compared to the year ended December 31, 2014

During the years ended December 31, 2015 and 2014, we had net income of $2,753,593 and a net loss of $283,101, respectively, for an increase in net income of $3,036,694. The increase in net income is due to an increase in non-cash charges of $3,037,324. The change in non-cash charges consisted of an increase in the change in fair value of derivative liabilities of $3,006,295.

For the years ended December 31, 2015 and 2014, we recognized operating expenses of $283,731 and $753,287, respectively, for a decrease of $469,556. The decrease in operating expenses is primarily due to an approximate $455,000 decrease in consulting fees as consulting fees during 2015 were capitalized as exploration costs as part of oil and gas properties. Operating expenses also decreased by an approximate $55,5000 for professional fees.

INTEREST AND OTHER INCOME (EXPENSE)

Included in other income (expense) for the year ended December 31, 2015, is a gain of $3,006,295 relating to the change in fair value of derivative liability resulting from a decrease in the fair value of the derivative liability off-set by the issuance of common stock warrants. The decrease in derivative liability was the result of a decrease in the Company’s stock price at December 31, 2015 compared to 2014. See Note 5 of the Financial Statements for more on the change in the derivative liability.

As of December 31, 2015, we had $2,541 in cash, a decrease of $116,332 from December 31, 2014. The decrease in cash is primarily due to an increase in investing activities from the acquisition of additional oil and gas properties. Management estimates that the Company will require approximately $525,000 to fund planned operations for the next twelve months. 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 2017 our capital requirements will mostly be associated with the maintenance of our lease payments to the Crown. 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, 2015 was $214,127 compared to $247,614 in 2014. The decrease in cash used in operating activities was primarily due to a decrease in operating expense during 2015 compared to 2014.

Cash used in investing activities during the year ended December 31, 2015 was $120,949 compared to cash used in investing of $425,987 in 2015. During 2015, the Company had less acquisition of oil and gas interests.

The Company generated net cash inflows from financing activities of $248,114 compared to $371,200 in 2015 The Company raised $220,000 in funds from a series of private placements during 2015. See Note 9 to the financial statements for more information.

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.

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, 2016 and 2015 (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, 2016.

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 and British Columbia. 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, 2016 and December 31, 2015 or as of the date of this report.

F. Tabular Disclosure of Contractual Obligations

The following table outlines contractual obligations at December 31, 2016.

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:

Peace River property leases

1,112,965

212,289

636,867

236,929

26,880

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

1,112,965

212,289

636,867

236,929

26,880

The Peace River Project is currently comprised of 62 leases with the government of the Province of Alberta, Canada requiring annual lease payments of USD $212,289 (CDN $158,113). The leases are fifteen-year leases that expire beginning June 11, 2021 through January 6, 2026.

At December 31, 2016, the Company had trade payables and accrued liabilities of $184,604. All of these obligations are due in less than one year.

At December 31, 2016, the Company had a derivative liability of $779,796 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:

Please refer to Note 3 of 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, President, Chief Executive Officer, Chief Financial Officer, Secretary and Director	May 22, 2014

Michael Ranger	Director	July 11, 2012

(1)	Mr. Newton was appointed as Chairman of the Board on May 22, 2014 and was appointed President, Chief Executive Officer, Chief Financial Officer, Secretary and Director on June 25, 2015.

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.

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. Executive Compensation

The following table shows compensation paid to the directors and members of its administrative, supervisory or management bodies of the Company for the most recently completed financial year.

Name

Title

Year

Salary

Bonus

Stock
Options
Granted

Other
Annual
Compensation

Restricted
Stock
Awarded

LTIP
Payouts
($)

All Other
Compensation

Trevor Newton(1)

Director – Chairman,
President, CEO
Secretary

2016

75,240

(2)

–

2015

16,001

–

200,000

–

2014

–

200,000

Michael Ranger

Director

2016

12,662

(3)

–

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

(2)	The Company and Mr. Newton agreed to issue stock in lieu of cash for the amount owed of $75,240 by issuing restricted common stock of the Company totaling 234,950 shares .

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 2016, 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, President, CEO, Secretary and Director supervises the Company’s operations. Mr. Newton does not bill the Company for these services, however he does have a service agreement with the Company. The Company capitalized oil and gas exploration costs of $75,240 as of December 31, 2016, under this agreement. The Company recognized $12,221 as consulting fees during the year ended December 31, 2015 under this agreement. The Company and Mr. Newton agreed to issue stock in lieu of cash for the amount owed of $75,240 by issuing restricted common stock of the Company. The 2016 average stock price was used, which represents the period of service, to determine the number of shares to issue for a total of 234,950 shares. The shares have not been issued as of the date of this report. The agreement does not provide for termination benefits of any kind.

Dr. Ranger, Director, has a service agreement with the Company for his Director services. The Company capitalized oil and gas exploration costs of $12,662 and $nil during the years ended December 31, 2016 and 2015, respectively, under this agreement. The Company and Mr. Ranger agreed to issue stock in lieu of cash for a portion of his services billed totaling $7,448 by issuing restricted common stock of the Company. The 2016 average stock price was used, which represents the period of service, to determine the number of shares to issue for a total of 23,257 shares. The shares have not been issued as of the date of this report. The agreement does not provide for termination benefits of any kind.

The issuances of the securities to Mr. Newton and Dr. Ranger, were offered and sold pursuant to an exemption from the registration requirements under Section 4(a)(2) of the Securities Act 1933, as amended and Rule 506 of Regulation D promulgated thereunder since, among other things, the transactions did not involve a public offering and the securities were acquired for investment purposes only and not with a view to or for sale in connection with any distribution thereof.

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, 2016 or during the 2015 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 the ownership of outstanding shares of the Company held by each of our officers and directors as of May 15, 2017. 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		1,669,605		15.36%		280,000

Trevor Newton(2)		1,669,605		15.36%		200,000

Michael Ranger(3)		–		–		80,000

(1)	Based on 10,475,793 shares of common stock issued and outstanding as of May 15, 2017.
(2)	Mr. Newton was awarded 200,000 stock options to purchase common shares of the Company at an exercise price of $1.40 on July 1, 2014 and are fully vested.
(3)	Dr. Michael Ranger was awarded 20,000, 20,000, 20,000 and 20,000 stock options to purchase common shares of the Company at an exercise price of $22.85, $6.1, $7.0 and $1.4 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 May 15, 2017 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			1,669,605				15.36%

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

None

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

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

7.A.2 Share Ownership.

On May 15, 2017, the Company had one hundred seventy-six (176) registered shareholders holding 10,475,793 shares. Of these, one hundred forty-three (143) registered shareholders holding 1,773,261 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

Acquisition of Oil and Gas Properties

On February 22, 2016, the Company entered into two purchase / sale agreements acquiring a total of 45 leases, representing 39,680 hectares (98,051 acres) in the Peace River area of Alberta. One of the purchase / sale agreements was with a related party. The Company paid for the acquisition of these leases by the issuance of restricted 3,997,431 shares of its common stock valued at $2.17 per share reduced by the carrying value of notes receivable, including accrued interest, from the two parties. As of February 22, 2016, the total notes receivable, plus accrued interest, was $271,380 and the value of the share issuance was $867,433 resulting in a net purchase price of $1,138,823.

Notes payable to related party

In December 2015, the Company borrowed $6,553 ($9,000 Canadian) under two a note agreement with related parties. The lender is related parties through an immediate family relationship with officers or directors of the Company. The note bears interest at the Bank of Canada Prime rate plus 1%. The Company may repay the loan and outstanding interest thereon by giving notice to the lender 15 days prior to the anticipated repayment. At December 31, 2016, the effective interest rate on this note payable was 3.7%. The balance of notes payable to related parties at December 31, 2016 was $6,963. The Company recognized interest expense of $264 and $nil for the years ended December 31, 2016 and 2015, respectively, in its Statement of Operations and Comprehensive Income.

Consulting fees

Mr. Newton is the President and a member of the Board of Directors of the Company. Mr. Newton does not bill the Company for his services as President; however, he has a service agreement with the Company. Pursuant to this agreement, the Company capitalized oil and gas exploration costs and an accrued liability of $75,240 as of December 31, 2016. The Company recognized $16,001 as consulting fees during the year ended December 31, 2015. The Company and Mr. Newton agreed to issue stock in lieu of cash for the amount of $75,240 by issuing restricted common stock of the Company. As of the date of this filing, the Company has yet to issue total shares of 234,950 to settle this liability.

Mr. Michael Ranger is a member of the Board of Directors of the Company. Mr. Ranger does not receive compensation for his services as a member of the board; however, he has a service agreement with the Company. Pursuant to this agreement, the Company capitalized oil and gas exploration costs and an accrued liability of $12,662 and $nil during the years ended December 31, 2016 and 2015, respectively. The Company and Mr. Ranger agreed to issue stock in lieu of cash for a portion of this services billed in the amount of $7,448. As of the date of this filing, the Company has yet to issue total shares of 23,258 to settle this liability.

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 Fruci & Associates II, PLLC is included herein immediately preceding the financial statements.

Audited Financial Statements:

Fiscal years ended December 31, 2016, 2015 and 2014.

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
2016	$0.60	$0.20
2015	$1.50	$0.30
2014	$3.50	$1.10
2013	$3.10	$1.10
2012	$1.50	$.50

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

Financial Quarter		Market Price
Year	Quarter	High Price	Low Price
2016	Fourth Quarter of 2016	$0.30	$0.20
	Third Quarter of 2016	$0.50	$0.20
	Second Quarter of 2016	$0.50	$0.30
	First Quarter of 2016	$0.60	$0.20

2015	Fourth Quarter of 2015	$0.90	$0.30
	Third Quarter of 2015	$1.40	$0.60
	Second Quarter of 2015	$1.60	$0.80
	First Quarter of 2015	$1.50	$0.80

2014	Fourth Quarter of 2014	$2.60	$1.10
	Third Quarter of 2014	$3.50	$1.40
	Second Quarter of 2014	$1.80	$1.30
	First Quarter of 2014	$2.00	$1.20

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 May 15, 2017, the exchange rate in effect for Canadian dollars exchanged for United States dollars, expressed in terms of Canadian dollars was $ 1.34. 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, 2016, our disclosure controls and procedures were not 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 14d-14(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, 2016. In making the assessment, management used the criteria issued by the Committee of Sponsoring Organizations of the Treadway Commission’s (COSO) 2013 Internal Control-Integrated Framework. Based on its assessment as of December 31, 2016, management has identified material weaknesses specifically in regard to: the need for a more formalized process for annually evaluating its assets for impairment; the need for adequate redundancy and levels of supervision/review in the preparation of the Company’s financial statements; the need for more resources to ensure more effective segregation of operational duties. A material weakness is a deficiency, or a combination of deficiencies, in internal controls, such that there is a reasonable possibility that a material misstatement of the Company’s annual or interim financial statements may not be prevented or detected on a timely basis. Because of the inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that all control issues within the Company have been detected. However, the Company plans to continue to evaluate and work to improve its internal controls in these areas. the Company’s internal controls over financial reporting were effective.

Changes in Internal Control over Financial Reporting

Except as noted above, there were no changes in our internal control over financial reporting, as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act, during our fiscal quarter ended December 31, 2016 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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, 2016, management assessed the effectiveness of our internal control over financial reporting, and based on that evaluation, they concluded that through December 31, 2016 and to date, the internal controls and procedures were not effective due to the material weaknesses described above. 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, 2016, 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.

AUDIT COMMITTEE INFORMATION

The mandate of the Audit Committee is set forth in Appendix "A" attached hereto.

Composition of the Audit Committee

The Audit Committee is currently comprised of Trevor Newton (Chairman) and Dr. Michael Ranger, all of whom are financially literate under National Instrument 52-110 - Audit Committees (“ NI 52-110 ”) . Dr. Ranger is independent under NI 52-110. Mr. Newton is not considered independent under NI 52-110 as he serves as an executive officer of the Company.

The Corporation acknowledges that the composition of the Audit Committee does not currently comply with the requirements of NI 52-110.

Relevant Education and Experience

The following relevant education and experience of the members of the Audit Committee have been used in assessing their financial literacy:

Trevor Newton

Mr. Newton has assisted private and public companies in their financing, project acquisition, and development since 1996. Mr. Newton has a B.Sc. in Economics from the University of Victoria and an M.A. in Economics from Simon Fraser University.

Michael Ranger

Dr. Ranger is an independent petroleum consultant and is a director of Canadex Resources Ltd. Dr. Ranger has a prolific career providing services to an array of the world's largest oil companies. 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.

Audit Committee Oversight

At no time since incorporation was a recommendation of the audit committee to nominate or compensate an external auditor not adopted by the Board of Directors of the Corporation.

Pre-Approval Policies and Procedures

To safeguard the continued independence of the Corporation’s external auditors, all services (including non-audit services) to be rendered by the Corporation’s external auditors and any of their related entities to the Corporation or any subsidiary of the Corporation, and all related terms of engagement, must be the subject of pre-approval by the Audit Committee.

Reliance on Certain Exemptions

As the Company is a “venture issuer” and may avail itself of exemptions from the Requirement of Part 3 – Composition of the Audit Committee which requires the independence of each member of the audit committee.

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 years ended December 31, 2016.

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 three 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, 2016(1)(2)		Fiscal year ending December 31, 2015 (1)		Fiscal year ending December 31, 2014 (1)(3)
Audit Fees	$	12,500	$	12,500	$	15,800
Audit Related Fees		–		–		–
Tax Fees		–		–		–
All Other Fees		–		–		–
	$	12,500	$	12,500	$	15,800

(1)	As of December 31, 2016, 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, 2016
(3)	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).

Strata Oil & Gas Inc.

Financial Statements

December 31, 2016

Contents

Report of Independent Registered Public Accounting Firm	F-2
Balance Sheets as of December 31, 2016 and 2015	F-3
Statements of Operations and Comprehensive Income (Loss) for the years ended December 31, 2016, 2015 and 2014	F-4
Statements of Changes in Stockholders’ Equity (Deficit) as of December 31, 2016	F-5
Statements of Cash Flows for the years ended December 31, 2016, 2015 and 2014	F-6
Notes to the Financial Statements	F-7

F- 1

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders

Strata Oil & Gas Inc.

Alberta, Canada

Opinion on the Financial Statements

We have audited the accompanying balance sheets of Strata Oil & Gas Inc. (“the Company”) as of December 31, 2016 and 2015, and the related statements of operations and comprehensive income (loss), changes in shareholders’ equity (deficit), and cash flows for each of the three years ended December 31, 2016, and the related notes (collectively referred to as the financial statements). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2016 and 2015, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2016, in conformity with accounting principles generally accepted in the United States of America.

Basis for Opinion

These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audit. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audit, we are required to obtain an understanding of internal control over financial reporting, 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.

Our audit included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audit also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audit provides a reasonable basis for our opinion.

Consideration of the Company’s Ability to Continue as a Going Concern

The accompanying financial statements have been prepared assuming that the Company will continue as a going concern. As discussed in Note 2 to the financial statements, the Company has incurred net losses since inception, has negative cash flows from operations, and is expected to incur further negative operating cash flows in the foreseeable future. These factors raise substantial doubt about the Company’s ability to continue as a going concern. Management’s plans in regard to these matters are also described in Note 2. The financial statements do not include any adjustments that might result from the outcome of this uncertainty.

Fruci & Associates II, PLLC

We have served as the Company’s auditor since 2017.

Spokane, Washington
January 16, 2018

F- 2

STRATA OIL & GAS INC.

BALANCE SHEETS

(Expressed in US Dollars)

	December 31,
	2016			2015
ASSETS
Current assets
Cash	$	7,881		$	2,541
GST receivables		1,660			1,164
Notes receivable from related parties		–			–
Prepaid expenses		1,365			–
Total current assets		10,906			3,705

Reclamation deposits		121,391			116,806
Notes receivable from related parties		–			217,461
Oil and gas property interest (unproved)		–			6,237,026
Total assets	$	132,297		$	6,574,998

LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT)
Current liabilities
Accounts payable and accrued liabilities	$	91,326		$	13,866
Accounts payable and accrued liabilities - related party		93,278			1,950
Notes payable		6,963			6,503
Derivative liability		779,796			1,153,491
Total current liabilities		971,363			1,175,810

Asset retirement obligation		138,728			128,301
Total liabilities		1,110,091			1,304,111

Commitments and Contingencies

Stockholders' equity (deficit)
Preferred stock: no par value, unlimited shares authorized and none issued		–			–
Common stock: no par value, unlimited shares authorized; 14,215,016 and 9,169,418 shares issued and outstanding at December 31, 2016 and 2015; respectively		–			–
Additional paid-in capital		22,919,431			21,975,988
Stock subscriptions received		–			21,514
Accumulated deficit		(23,525,737	)		(16,193,263	)
Accumulated other comprehensive income		(371,488	)		(533,352	)
Total stockholders' equity (deficit)		(977,794	)		5,270,887
Total liabilities and Stockholders' equity (deficit)	$	132,297		$	6,574,998

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,
	2016			2015			2014
Operating Expenses:
Professional fees	$	64,740		$	70,364		$	125,868
Office and sundry		8,443			20,973			30,377
Consulting fees		6,172			128,630			584,019
Transfer agent fees		1,861			4,787			2,478
Loss on disposal of properties		–			45,355			–
Accretion expense		6,566			13,622			10,545
Impairment of oil & gas properties		7,831,570			–			–
Total operating expenses		7,919,352			283,731			753,287

Other income (expense):
Interest income		998			–			1,287
Interest income, related party		1,153			8,015			3,637
Interest expense		(264	)		–			–
Foreign exchange loss		111			23,104			(1,237	)
Change in fair value of derivative liability		584,880			3,006,205			466,499
Total other income		586,878			3,037,324			470,186

Net income (loss)		(7,332,474	)		2,753,593			(283,101	)

Other comprehensive income (loss)
Foreign currency translation adjustment		161,864			(725,671	)		(266,839	)
Comprehensive (loss) income	$	(7,170,610	)	$	2,027,922		$	(549,940	)
Basic and diluted earnings (loss) per share (Note 8)
Basic income (loss) per common share	$	(0.56	)	$	0.30		$	(0.03	)
Diluted income (loss) per common share	$	(0.56	)	$	0.30		$	(0.03	)
Basic weighted average number of shares outstanding		13,035,203			9,115,416			8,719,125
Diluted weighted average number of shares outstanding		13,035,203			9,161,527			8,719,125

The accompanying notes are an integral part of these financial statements.

F- 4

STRATA OIL & GAS INC.

STATEMENTS OF CHANGES IN STOCKHOLDERS’ EQUITY (DEFICIT)

(Expressed in US Dollars)

Common Stock
Shares

Additional
Paid-in
Capital

Stock
Subscriptions
Payable

Accumulated
Deficit

Accumulated Other
Comprehensive
Income

Total
Stockholders'
Equity (Deficit)

Balance December 31, 2013

8,572,850

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

65,250

69,600

–

69,600

Private placement, common stock and warrants issuance for cash

300,218

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

8,938,318

21,905,643

–

(18,946,856

)

192,319

3,151,106

Stock compensation, non-employees

–

41,845

–

41,845

Private placement, common stock and warrants issuance for cash

231,100

219,990

–

219,990

Derivative liability adjustment

–

(191,490

)

–

(191,490

)

Stock subscriptions received

–

21,514

–

21,514

Net loss and comprehensive loss

–

2,753,593

(725,671

)

2,027,922

Balance December 31, 2015

9,169,418

21,975,988

21,514

(16,193,263

)

(533,352

)

5,270,887

Private placement, common stock and warrants issuance for cash and subscriptions payable

668,167

169,700

(21,514

)

–

148,186

Derivative liability adjustment

–

(169,700

)

–

(169,700

)

Private placement, common stock

380,000

76,000

–

76,000

Issuance of stock for purchase of oil properties from related parties

3,997,431

867,443

–

867,443

Net loss and comprehensive loss

–

(7,332,474

)

161,864

(7,170,610

)

Balance December 31, 2016

14,215,016

22,919,431

–

(23,525,737

)

(371,488

)

(977,794

)

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 ending December 31,
	2016			2015			2014
Cash flows from operating activities
Net income (loss)	$	(7,332,474	)	$	2,753,593		$	(283,101	)
Adjustments to reconcile net income (loss) to net cash used in operating activities
Stock option expense for consulting fees		–			41,845			421,923
Accrued interest		–			–			(3,637	)
Accretion expense		6,566			13,622			10,545
Change in fair value of derivative liability		(584,880	)		(3,006,205	)		(466,499	)
Loss on disposal of oil and gas properties		–			45,355			–
Impairment of oil and gas properties		7,831,570			–			–
Change in assets and liabilities
Interest receivable		(1,153	)		(8,693	)		–
GST receivable		(468	)		7,837			(2,616	)
Prepaid expenses		(1,385	)		4,012			(4,012	)
Accounts payable		48,871			(35,056	)		47,396
Accrued liabilities		15,329			(30,437	)		32,387
Net cash used in operating activities		(18,024	)		(214,127	)		(247,614	)

Cash flows from investing activities
Deposits		(998	)		(4,996	)		(23,892	)
Acquisition of oil and gas interests		(156,060	)		(62,285	)		(298,786	)
Notes receivable advances		–			(33,353	)		–
Notes receivable advances to related party		(42,063	)		(20,315	)		(103,309	)
Net cash used in investing activities		(199,121	)		(120,949	)		(425,987	)

Cash flows from financing activities
Proceeds from issuance of common stock and warrants		76,000			–			301,600
Proceeds from the exercise of warrants		–			–			69,600
Proceeds from issuance of common stock		147,000			219,990			–
Stock subscriptions received		–			21,514			–
Proceeds from loan financing		–			13,835			–
Repayment of loan financing		–			(7,225	)		–
Net cash provided by financing activities		223,000			248,114			371,200

Foreign exchange effect on cash		(515	)		(29,370	)		(19,338	)
Net increase (decrease) in cash		5,340			(116,332	)		(321,739	)
Cash, beginning balance		2,541			118,873			440,612
Cash, ending balance	$	7,881		$	2,541		$	118,873

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

Non-cash investing and financing activities
Reclass of additional paid-in capital to derivative liability	$	169,700		$	191,490		$	301,600
Oil and gas acquisitions accrued	$	94,654		$	–		$	–
Shares issued for acquisition of oil and gas properties	$	867,443		$	–		$	–
Note receivable used for acquisition of oil and gas properties	$	271,380		$	–		$	–
Common stock issued for subscription payable	$	21,514		$	–		$	–

The accompanying notes are an integral part of these financial statements.

F- 6

STRATA OIL & GAS INC.

Notes to the Financial Statements

NOTE 1. NATURE OF BUSINESS

Strata Oil & Gas Inc. (the ‘Company’) is currently engaged in the acquisition, exploration and if warranted feasible development of heavy oil projects in the Peace River oil sands region in Northern Alberta, Canada. The Company was incorporated under the laws of the State of Nevada on November 18, 1998 and commenced operations in January 1999. The Company completed its initial public offering in February 2000.

The Company is presently incorporated under the Canada Business Corporations Act.

As of December 31, 2016, the Company had interests in 62 leases covering 60,672 hectares in the Peace River oil sands region.

NOTE 2. ABILITY TO CONTINUE AS A GOING CONCERN

As shown in the accompanying financial statements, the Company has not realized any revenue from its present operations. During the year ended December 31, 2016, the Company incurred a net loss of $7,332,474 and had negative cash flows from operations of $18,024 and is expected to incur further negative operating cash flows in the foreseeable future. The Company has an accumulated deficit of $23,525,737 at December 31, 2016. These conditions raise substantial doubt regarding the Company’s ability to continue as a going concern. The financial statements have been prepared on a going concern basis, which contemplates realization of assets and liquidation of liabilities in the ordinary course of business.

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 $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 obtain sufficient capital to continue operations in the next 12 months. 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.

NOTE 3. SIGNIFICANT ACCOUNTING POLICIES

Basis of Presentation

The financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“US GAAP”) and pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”).

Management’s Estimates and Assumptions

The preparation of financial statements in conformity with US GAAP 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.

F- 7

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.

On an annual basis management evaluates the carrying value of the Company’s leases and associated assets 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, geographic and geologic data, and also the commodity price forecast. As of December 31, 2016, the Company decided to fully impair certain of its assets primarily relating to unproved leases and legacy wells for a total impairment of $7,831,570. As of December 31, 2015, no impairment was recognized.

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 were no cash equivalent balances for the years ended December 31, 2016, 2015 or 2014.

GST Receivables

Goods and Services Tax (GST) receivables are presented net of an allowance for doubtful accounts. Receivables consist of goods and services input tax credits. The allowance for doubtful accounts on GST receivables was $nil at December 31, 2016, 2015 and 2014.

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, 2016, 2015 and 2014 (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- 8

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 Company 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. Equity transactions have been translated at historical rates. The Company’s results of operations have been translated using the average daily exchange rate for the fiscal year. 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 Options

The Company measures all employee stock-based compensation awards using a fair value method on the date of grant and recognizes such expense in its consolidated financial statements over the requisite service period. The Company uses the Black-Scholes pricing model to determine the fair value of stock-based compensation awards on the date of grant. The Black-Scholes pricing model requires management to make assumptions regarding option lives, expected volatility, and risk free interest rates.

The Company accounts for non-employee stock-based awards in accordance with the provision of ASC 505, “Equity Based Payments to Non-Employees” (“ASC 505”), which requires that such equity instruments are recorded at their fair value on the measurement date. The measurement of stock-based compensation is subject to periodic adjustment as the underlying equity instruments vest. The Company uses the Black-Scholes pricing model to determine the fair value of stock-based compensation awards. The Black-Scholes pricing model requires management to make assumptions regarding option lives, expected volatility, and risk free interest rates.

F- 9

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).

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. See Note 10 “Earnings Per Share” for further details.

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 balance sheet date. Liabilities measured at fair value are summarized as follows as of:

	Fair Value Measurement at				Fair Value Measurement at				Fair Value Measurement at
	December 31, 2016				December 31, 2015				December 31, 2014
	Using				Using				Using
	Level 3		Total		Level 3		Total		Level 3		Total
Liabilities:
Derivative liabilities	$	779,796	$	779,796	$	1,153,491	$	1,153,491	$	4,482,296	$	4,482,296

The Company measures and reports 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. A slight change in an unobservable input like historical volatility could have a significant impact on the fair value measurement of the derivative liabilities. See Note 5 “Derivative Liabilities” 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.

F- 10

Related Party Transactions

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

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.

In February 2015, the FASB issued ASU 2015-02, Amendments to the Consolidation Analysis , which makes changes to both the variable interest model and the voting model, affecting all reporting entities involved with limited partnerships or similar entities, particularly industries such as the oil and gas, transportation and real estate sectors. In addition to reducing the number of consolidation models from four to two, the guidance simplifies and improves current guidance by placing more emphasis on risk of loss when determining a controlling financial interest and reducing the frequency of the application of related-party guidance when determining a controlling financial interest in a VIE. The requirements of the guidance are effective for annual reporting periods beginning after December 15, 2015, including interim periods within that reporting period, with early adoption permitted. We adopted this guidance on January 1, 2016. The adoption of this guidance did not have a material impact on the Company’s financial statements.

In August 2015, the FASB issued ASU 2014-15, Presentation of Financial Statements Going Concern (Subtopic 205-40) - Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern. Currently, there is no guidance in U.S. GAAP about management’s responsibility to evaluate whether there is substantial doubt about an entity’s ability to continue as a going concern or to provide related footnote disclosures. The amendments in this update provide that guidance. The amendments are intended to reduce diversity in the timing and content of footnote disclosures. The amendments require management to assess an entity’s ability to continue as a going concern by incorporating and expanding upon certain principles that are currently in U.S. auditing standards. Specifically, the amendments (1) provide a definition of the term “substantial doubt,” (2) require an evaluation every reporting period, including interim periods, (3) provide principles for considering the mitigating effect of management’s plans, (4) require certain disclosures when substantial doubt is alleviated as a result of consideration of management’s plans, (5) require an express statement and other disclosures when substantial doubt is not alleviated, and (6) require an assessment for a period of one year after the date that the financial statements are issued (or available to be issued). The amendments in this update are effective for annual periods ending after December 15, 2016, and early adoption is permitted. The Company adopted this guidance during the year ended December 31, 2016. Refer to Note 2 “Ability to Continue as a Going Concern” for further information.

In November 2015, FASB issued ASU No. 2015-17,” Balance Sheet Classification of Deferred Taxes”. ASU No. 2015-17 requires that deferred tax liabilities and assets be classified as noncurrent in a classified statement of financial position. ASU No. 2015-17 is effective for financial statements issued for fiscal years beginning after December 15, 2016, and interim periods within those fiscal years. The Company adopted this ASU No. on January 1, 2016 and its adoption did not have a material impact on the Company’s financial position and results of operations.

In March 2016, the FASB issued ASU No. 2016-09, Compensation-Stock Compensation (Topic 718), Improvements to Employee Share-Based Payment Accounting. Under ASU No. 2016-09, companies will no longer record excess tax benefits and certain tax deficiencies in additional paid-in capital (“APIC”). Instead, they will record all excess tax benefits and tax deficiencies as income tax expense or benefit in the income statement and the APIC pools will be eliminated. In addition, ASU No. 2016-09 eliminates the requirement that excess tax benefits be realized before companies can recognize them. ASU No. 2016-09 also requires companies to present excess tax benefits as an operating activity on the statement of cash flows rather than as a financing activity. Furthermore, ASU No. 2016-09 will increase the amount an employer can withhold to cover income taxes on awards and still qualify for the exception to liability classification for shares used to satisfy the employer’s statutory income tax withholding obligation. An employer with a statutory income tax withholding obligation will now be allowed to withhold shares with a fair value up to the amount of taxes owed using the maximum statutory tax rate in the employee’s applicable jurisdiction(s). ASU No. 2016-09 requires a Company to classify the cash paid to a tax authority when shares are withheld to satisfy its statutory income tax withholding obligation as a financing activity on the statement of cash flows. Under current U.S. GAAP, it was not specified how these cash flows should be classified. In addition, companies will now have to elect whether to account for forfeitures on share-based payments by (1) recognizing forfeitures of awards as they occur or (2) estimating the number of awards expected to be forfeited and adjusting the estimate when it is likely to change, as is currently required. The amendments of this ASU are effective for reporting periods beginning after January 1, 2016, with early adoption permitted but all of the guidance must be adopted in the same period. The Company adopted this on January 1, 2016. The Company has evaluated the impact of ASU No. 2016-09 and has determined that the adoption of the impact of forfeitures, net of income taxes, will not have a material impact on the Company’s future financial statements.

F- 11

In February 2017, the FASB has issued ASU No. 2017-05, Other Income – Gains and Losses from the Derecognition of Nonfinancial Assets (Subtopic 610-20) . This amendment clarifies that nonfinancial assets within the scope of Subtopic 610-20 may include nonfinancial assets transferred within a legal entity to a counterparty. For example, a parent may transfer control of nonfinancial assets by transferring ownership interests in a consolidated subsidiary. A contract that includes the transfer of ownership interests in one or more consolidated subsidiaries is within the scope of Subtopic 610-20 if substantially all of the fair value of the assets that are promised to the counterparty in a contract is concentrated in nonfinancial assets. The amendment clarifies that an entity should identify each distinct nonfinancial asset or in substance nonfinancial asset promised to a counterparty and derecognize each asset when a counterparty obtains control of it. This is effective for annual reporting periods beginning after December 15, 2017, including interim reporting periods within that reporting period. We do not expect the adoption of this standard to have a material effect on our consolidated financial statements and related disclosures.

In August 2016, the FASB issued ASU No. 2016-15 which addresses how certain cash receipts and cash payments are presented and classified in the statement of cash flows with the objective of reducing existing differences in the presentation of these items. The amendments in ASU No. 2016-15 are to be adopted retrospectively and will become effective in the first quarter of fiscal 2019. The Company is evaluating the impact of adopting this standard on its consolidated statement of cash flows. We do not expect the adoption of this standard to have a material effect on our consolidated financial statements and related disclosures.

In November 2016, the FASB issued ASU No. 2016-18 which require that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. As a result, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. The amendments do not provide a definition of restricted cash or restricted cash equivalents. The guidance is effective for annual reporting periods after December 15, 2017, and interim periods within those fiscal years. The amendments should be applied using a retrospective transition method to each period presented. The Company is evaluating the impact of adopting this standard on its consolidated statement of cash flows.

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.

NOTE 4. NOTES RECEIVABLE, RELATED PARTIES

During the period December 27, 2013 through February 22, 2016, the Company entered into several unsecured short-term note receivable agreements totaling $123,213 (C$165,432), principal plus interest, with a related party through common directors. The notes receivable included an option agreement with the borrower for development rights on a portfolio of oil sands leases in Alberta. If the option agreement were exercised, the outstanding balances payable under the note receivable would be applied towards option payments.

F- 12

During the period December 27, 2013 through June 30, 2015, the Company entered into several unsecured short-term note receivable agreements totally $52,677 (C$70,726)), principal plus interest, with a second borrower who was also a related party through common directors. The notes receivable included an option agreement with the borrowers for development rights on a portfolio of oil sands leases in Alberta. If the option agreement were exercised, the outstanding balances payable under the note receivable would be applied towards option payments. As of June 25, 2015, the related party relationship ceased to exist as the common director step-down. During the period June 30, 2015 through February 22, 2016, the Company entered into additional unsecured short-term note receivable agreements with this borrower totally $78,303 (C$105,133). Total notes receivable from this borrower were $130,980 (C$175,859).

All note receivable agreements bore interest at the Bank of Canada prime rate plus 1%. The borrower could 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. All notes receivable included an option agreement with the borrowers for development rights on a portfolio of oil sands leases in Alberta. If the option agreement were exercised, the outstanding balances payable under the note receivable would be applied towards option payments.

On February 22, 2016, the Company and the borrowers entered into a purchase and sale agreement whereby the Company elected to acquire all the rights and obligations associated with certain oilsands leases. As part of the purchase price, the notes receivable were applied towards the payment for the lease rights. Accordingly, the notes receivable plus accrued interest were $nil as of December 31, 2016. See Note 6 “Oil Properties” for additional discussion of the lease acquisitions.

For the years ended December 31, 2016 and 2015, the Company advanced $15,987 (C$19,000) and $20,315 (C$38,500), respectively, under the short-term note agreements with the related party. The Company recognized $502 (C$835) and $4,217 (C$5,428) in accrued interest income for the years ended December 31, 2016 and 2015, under the terms of the note agreements with the related party.

For the years ended December 31, 2016 and 2015, the Company advanced $26,706 (C$38,800) and $30,353 (C$63,700), respectively, under the short-term note agreements. The Company recognized $651 (C$874), $2,581 (C$3,322) and $231 in accrued interest income for the years ended December 31, 2016, 2015 and 2014, under the terms of the note agreements.

NOTE 5. DERIVATIVE LIABILITIES

Derivative liabilities consist of common stock warrants with an exercise price in a different currency than the Company’s functional currency and they are accounted for as separate liabilities measured at their respective fair values as follows:

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
Fair value of warrants issued in private placements reclassified from equity		191,490
Change in fair value of derivative liabilities		(3,006,205	)
Foreign exchange effect on derivative liability		(514,720	)
Balance, December 31, 2015	$	1,153,491
Fair value of warrants issued in private placements reclassified from equity		169,700
Fair value of warrants issued in private placements recognized as derivative expense		59,064
Change in fair value of derivative liabilities		(643,944	)
Foreign exchange effect on derivative liability		41,485
Balance, December 31, 2016	$	779,796

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

	2016	2015	2014
Volatility	254.90%	202.10%	1.01 to 1.79%
Expected life	.2 to 7 years	1 to 8 years	1 to 8 years
Risk-free interest rate	0.74% - 1.4%	.048 % to 1.36%	147.1%
Dividend yield	0.00%	0.00%	0.00%

F- 13

NOTE 6. OIL AND GAS PROPERTIES

Peace River Properties

During the period June 2006 through January 2007, the Company acquired the rights to multiple oilsands property leases with the Province of Alberta in the Peace River area of Alberta, Canada (the “Peace River Properties”). All 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 provincial government. All the leases are for a 15-year term, require minimum annual lease payments, and grant the Company the right to explore and develop oil sands on the respective lease. The specific transactions entered into by the Company are as noted below.

On February 22, 2016, the Company entered into two purchase / sale agreements acquiring a total of 45 leases, representing 39,680 hectares (98,051 acres) in the Peace River area of Alberta. One of the purchase / sale agreements was with a related party. The Company paid for the acquisition of these leases by the issuance of restricted 3,997,431 shares of its common stock valued at $0.217 per share reduced by the carrying value of notes receivable, including accrued interest, from the two parties. As of February 22, 2016, the total notes receivable, plus accrued interest, was $271,380 and the value of the share issuance was $867,433 resulting in a net purchase price of $1,138,823.

All the Company’s leases in the Peace River area are subject to royalties payable to the government of Alberta. 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.

The table below summarizes all lease properties of the Company as of the year ended December 31, 2016:

	Number of	Land Area	Annual Lease Payments
Acquisition Year	Leases	(Hectares)	CDN		USD
2005	6	9,152	32,032	/	$23,857
2006	29	35,328	123,585	/	$92,046
2007	21	13,312	46,592	/	$34,702
2008	5	1,280	4,480	/	$3,337
2011	1	1,600	5,600	/	$4,171
	62	60,672	212,289	/	$158,113

The Company completed drilling four exploratory wells during the fiscal year ended December 31, 2007 for a total cost of $2,796,637. Since 2007, the Company has performed several studies on the area and has developed a drilling program. The Company intends to move forward on the drilling program when adequate funding is available. For the years ended December 31, 2016 and 2015, the Company did not drill any exploratory wells. As of December 31, 2016, the Company decided to fully impair all of its unproved properties for a total impairment of $7,831,570. This decision was made due to: the historically low commodity prices; the general lack of investment activity in the sector; the general lack of new oil sands lease activity in the region; and the need to update our 51-101 studies to reflect the new COGEH standards. As of the years ended December 31, 2016, 2015 and 2014, the Company had oil and gas property balance of $nil and $6,237,026 and $7,423,966, respectively.

The following table sets forth the Company’s future minimum lease payments for the years ending December 31:

Year	Future Minimum Lease Payments
2017	$	212,289
2018		212,289
2019		212,289
2020		212,289
2021		180,257
Thereafter		83,552
Total	$	1,112,965

F- 14

NOTE 7. ASSET RETIREMENT OBLIGATIONS

During 2007, the Company drilled four wells on its Peace River Properties. 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 $138,724 and $128,301 at December 31, 2016 and 2015, respectively, based on an undiscounted total future liability of $218,226 (CDN$293,000). These payments are expected to be incurred between 2020 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 $6,559, $13,622 and $10,545 during the years ended December 31, 2016, 2015 and 2014, respectively, has been recorded in the Statements of Operations and Comprehensive Loss. The table below summarizes activity within our asset retirement obligation account.

	Years Ended December 31,
	2016		2015
Asset retirement obligations at beginning of year	$	128,301	$	138,049
Accretion expense		6,566		13,622
Liabilities incurred		–		–
Change in estimated obligations		–		–
Asset retirement obligations at end of year		134,867		151,671
Less: current retirement obligations		–		–
Change due to foreign exchange		3,861		(23,370	)
Long-term retirement obligations	$	138,728	$	128,301

NOTE 8. RELATED PARTY TRANSACTIONS

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

Notes payable to related party

In December 2015, the Company borrowed $13,835 ($19,000 Canadian) under two separate note agreements for $7,282 ($10,000 Canadian) and $6,553 ($9,000 Canadian) with related parties. The lenders are related parties through an immediate family relationship with officers or directors of the Company and a common director. The $7,282 loan from the immediate family relationship was repaid in its entirety at December 31, 2015.

The notes payable bear interest at the Bank of Canada Prime rate plus 1%. The Company may repay the loan and outstanding interest thereon by giving notice to the lender 15 days prior to the anticipated repayment. At December 31, 2016, the effective interest rate on these notes payable was 3.7%. The balance of notes payable to related parties at December 31, 2016 was $6,963. The Company recognized interest expense of $264 and $nil for the years ended December 31, 2016 and 2015, respectively, in its Statement of Operations and Comprehensive Income.

Consulting fees

Mr. Daems did 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 as consulting fees under the agreement.

F- 15

NOTE 9. SHARE CAPITAL

Pursuant to its articles of incorporation, the Company has an unlimited number of common stock shares available for issuance with no par value. As of December 31, 2016, the Company had 14,215,016 shares of common stock outstanding.

During the year ended December 31, 2016, the Company closed a series of private placements for a total of 623,167 units at $0.30 to $0.50 per unit for total offering proceeds of $138,000 and the payment of a subscription payable for cash received in 2015 of $21,514. Each unit consisted of one share of common stock for the Company and one Class A Warrant exercisable for one share of common stock at an exercise price of $0.20 to $0.50 for a period of five years from the date of placement. Warrants vest on the one year anniversary date.

On October 17, 2016, the Company closed a private placement with the President of the Company, totaling 45,000 units for total proceeds of $9,000. Each unit consisted of one share of common stock for the Company and one Class A Warrant exercisable for one share of common stock at an exercise price of $0.30 for a period of five years from the date of placement. Warrants vest on the one year anniversary date.

During the year ended December 31, 2016, the Company closed two private placements totaling 380,000 shares of common stock at $0.20 per common stock share for total proceeds of $76,000. A related party, a Company with common directors, participated in the transactions.

Refer to Note 6 Oil and Gas Properties for common stock shares issued for the acquisition of oil properties.

For the year ended December 31, 2015, 65,250 common share warrants were exercised at exercise prices of $0.90 to $1.50 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.

During the year ended December 31, 2015 the Company closed a series of private placements totaling 23,110 units at $0.90 to $1.00 per unit for total offering proceeds of $219,990. 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 $1.50 for a period of five years from the date of placement.

During the year ended December 31, 2014 the Company closed a series of private placements totaling 300,218 units at $0.90 to $1.20 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 $1.40 to $1.80 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, 65,250 common share warrants were exercised at exercise prices of $0.90 to $1.50 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.

The following table summarizes the assumptions used in the Black-Scholes models to estimate the grant date fair value of the warrants:

F- 16

The following table summarizes warrant activity during the years ended December 31, 2016 and 2015.

	Number of Warrants		Weighted Average Exercise Price		Warrants Exercisable		Weighted Average Exercise Price
Outstanding December 31, 2014		3,634,697	$	2.00		3,334,479	$	2.10
Issued		231,100	$	1.20		–		–
Canceled / exercised		–		–		–		–
Expired		–		–		–		–
Outstanding December 31, 2015		3,865,797	$	2.00		3,509,697	$	2.00
Issued		668,166	$	0.40		–		–
Canceled / exercised		–		–		–		–
Expired		–		–		–		–
Outstanding December 31, 2016		4,533,963	$	1.70		3,865,797	$	2.00

The following tables summarizes outstanding warrants as of December 31, 2016:

	Warrants Outstanding
Range of Exercise Price	Number of Warrants		Weighted Average Exercise Price		Remaining Contractual Life (yrs)
$0.03 - $0.010		1,320,933	$	0.70		3.9
$0.11 - $0.15		1,338,209	$	1.30		1.7
$0.15 - $0.20		1,199,392	$	1.90		2.2
$0.21 - $0.30		56,291	$	2.80		2.3
$0.31 - $0.50		62,737	$	4.50		1.8
$2.50 - $2.55		50,000	$	21.90		0.5
		4,533,963

The Company classified proceeds on December 31, 2016, 2015 and 2014 of $169,700, $191,490 and $301,600, respectively, from the private placements of common stock plus warrants as a derivative liability.

NOTE 10. 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.

The following table sets forth the basic and diluted net income per share computed for the years ended December 31, 2016, 2015 and 2014:

	For the years ended
	December 31,
	2016			2015			2014
Net income (loss)	$	(7,332,474	)	$	2,753,593		$	(283,101	)
Less: Non-cash income from changes in fair value of derivative liabilities		–			(133,395	)
Net loss - diluted	$	(7,332,474	)	$	2,620,198		$	(283,101	)
Weighted average common shares outstanding - basic		13,035,203			9,115,416			8,719,125
Common stock options		–			4,444			–
Common stock warrants - liability treatment		–			41,666			–
Weighted average common shares outstanding - diluted		13,035,203			9,161,527			8,719,125
Net income per share data:
Basic	$	(0.56	)	$	0.30		$	(0.03	)
Diluted		(0.56	)	$	0.30		$	(0.03	)

F- 17

The weighted average number of shares outstanding used in the computation of the basic and diluted net income per share does not include the effect of the following potential outstanding shares of common stock. The effects of these potentially outstanding shares were not included in the calculation of basic and diluted net income per share for 2016 because the effect would have been anti-dilutive.

	For the years ended
	December 31,
	2016		2015		2014
Common stock options		–		347,000		477,000
Common stock warrants - liability treatment		4,533,963		3,740,797		3,634,697
Potentially dilutive securities		4,533,963		4,087,797		4,111,697

NOTE 11. STOCK OPTION PLANS

Approval of the 2016 Stock Plan

In November 2016, the Board of Directors approved and the Company adopted the 2016 Stock Option Plan (“the 2016 Plan”). The 2016 Plan provides for the granting of up to 1,200,000 stock options to key employees, directors and consultants, of common shares of the Company. Under the 2016 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 2016 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).

As of December 31, 2016, there were 1,200,000 shares available for grant.

2006 Stock Option Plan

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 800,000 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).

In June 2016, the 2006 Plan expired so that no common stock options may be issued under this Plan.

Stock Option Activity

There were no stock options granted during the years ended December 31, 2016, 2015 and 2014.

F- 18

Activity under the 2016 and 2006 Plan is summarized as follows:

	Number of Stock Options Outstanding			Weighted Average Exercise Price		Weighted Average Remaining Contractual Life (Years)		Aggregate Intrinsic Value
Balance, December 31, 2013	100,000			$	7.30			$	0.00
Granted	377,000				1.70
Forfeited	–
Balance, December 31, 2014		477,000			2.90				0.00
Option granted		–			–
Options cancelled		(110,000	)		2.50
Options exercised		–			–
Balance, December 31, 2015		367,000			3.00				0.00
Option granted		–			–
Options cancelled		(20,000	)		22.90
Options exercised		–			–
Balance December 31, 2016		347,000			1.90		5.08		0.00

Exercisable at December 31, 2016		347,000			1.90		5.08		0.00

The following table summarizes information concerning outstanding and exercisable common stock options under the 2006 and 2016 Plans at December 31, 2016:

	Options Outstanding and Exercisable
Range of Exercise Price	Number of Options		Weighted Average Exercise Price		Remaining Contractual Life (yrs)
$0.70- $1.20		20,000	$	.70		5.53
$1.30 -$1.50		289,500	$	1.40		6.71
$1.60 - $4.00		5,000	$	3.00		3.92
$4.10 - $7.50		32,500	$	6.50		1.90

		347,000

There were no unvested common stock options under the 2016 or 2006 Plan at December 31, 2016.

As of December 31, 2016, 2015 and 2014, there was no unrecognized compensation cost related to all options granted and outstanding.

During the year ended December 31, 2015, the Company recorded consulting fees of $41,845 in the statement of operations related to stock options granted to non-employees.

The Company issues new shares when options are exercised.

F- 19

NOTE 12. INCOME TAXES

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

	2016			2015			2014
Loss carryforwards	$	661,000		$	627,200		$	956,000
Capital losses		5,000			5,000			5,000
Office equipment		12,500			12,500			12,500
Oil & Gas properties		2,222,000			1,691,000			2,133,900
Asset retirement obligation		83,300			76,700			63,000
Deferred tax asset		2,983,800			2,412,400			3,170,400

Less valuation allowance		(2,983,800	)		(2,412,400	)		(3,170,400	)
Deferred tax asset recognized	$	–		$	–		$	–

Upon continuation to Canada in 2004, all losses carried forward at that time expired. As of December 31, 2016, the Company had available to offset future taxable income a net Canadian operating loss carry-forwards of approximately $2.7 million. The carry-forwards began expiring in 2014 and unless utilized will continue to expire. The Company also has approximately $8.9 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, 2016, 2015 and 2014, changes in valuation allowance were $571,400, ($758,000) and ($25,700), 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 income loss as a result of the following differences:

	2016		2015		2014
Statutory federal income tax rate		-25%		-25%		-25%
Change in valuation allowance		19%		-24%		1%
%Non-deductible stock-based compensation		0%		-1%		-149%
Non%-deductible change in fair value of derivative liability		-117%		107%		165%
Non-deductible accretion expense		1%		4%		4%
Effect of foreign exchange		122%		-61%		2%
Effect of change in income tax rate		0%		0%		2%
		0%		0%		0%

The Company has evaluated its tax positions for the years ended December 31, 2016, 2015 and 2014 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 2016, 2015 and 2014.

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.

F- 20

NOTE 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.

NOTE 14. SUBSEQUENT EVENTS

For the nine months ended September 30, 2017, the Company received proceeds of $126,052 from private placements totaling 880,260 common shares issued to a related party by common director.

For the nine months ended September 30, 2017, the Company issued 258,208 common shares as stock in-lieu of cash to directors of the Company for services provided during the year ended December 31, 2016.

On May 5, 2017, the Company sold one of its impaired legacy wells for total proceeds of $40,112 (CDN$55,000).

On June 16, 2017, the Company appointed Dave Mahowich as Director.

On July 18, 2017, the Company affected a reverse stock split of the Company’s Common Stock at a reverse split ratio of 1-for-10, pursuant to a plan approved by the Company’s Board of Directors. The reverse stock split was declared effective by the Financial Industry Regulatory Authority (“FINRA”) on December 1, 2017. All shares throughout these financial statements have been retroactively adjusted to reflect the reverse stock split.

On November 12, 2017, the Company granted stock options to purchase up to 340,000 shares of common stock to four individuals. The options vested upon issuance, have a price of $0.05 and expire on November 12, 2027.

F- 21

Item 19. Exhibits

Exhibit No.	Description
1.1	Articles of Continuance (1)
1.2	Bylaws (1)
1.3	Audit Committee Charter (2)
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*	Fruci & Associates II, PLLC
15.2	2006 Stock Option Plan (3)
101.INS*	XBRL Instance Document
101.SCH*	XBRL Taxonomy Extension Schema Document
101.CAL*	XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF*	XBRL Definition Linkbase Document
101.LAB*	XBRL Label Linkbase Document
101.PRE*	XBRL Presentation Linkbase Document

* Filed herewith.

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

(2) Previously filed with the Company’s Annual Report on Form 20-F on April 29, 2015

(3) 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/A Amendment No. 2 and that it has duly caused and authorized the undersigned to sign this Annual Report on its behalf.

	STRATA OIL & GAS INC.
	(Registrant)


Dated: January 16, 2018	By: /s/ Trevor Newton
	Trevor Newton
	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/ Trevor Newton	Director	January 16, 2018
Trevor Newton

/s/ Michael Ranger	Director	January 16, 2018
Michael Ranger

/s/ Dave Mahowich	Director	January 16, 2018
Dave Mahowich