0001558891-17-000018.txt : 20170417 0001558891-17-000018.hdr.sgml : 20170417 20170417153940 ACCESSION NUMBER: 0001558891-17-000018 CONFORMED SUBMISSION TYPE: 10-K PUBLIC DOCUMENT COUNT: 64 CONFORMED PERIOD OF REPORT: 20161231 FILED AS OF DATE: 20170417 DATE AS OF CHANGE: 20170417 FILER: COMPANY DATA: COMPANY CONFORMED NAME: Tiger Oil & Energy, Inc. CENTRAL INDEX KEY: 0001386018 STANDARD INDUSTRIAL CLASSIFICATION: CRUDE PETROLEUM & NATURAL GAS [1311] IRS NUMBER: 205936198 FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-K SEC ACT: 1934 Act SEC FILE NUMBER: 000-53241 FILM NUMBER: 17764504 BUSINESS ADDRESS: STREET 1: 7230 INDIAN CREEK LN STREET 2: STE 201 CITY: LAS VEGAS STATE: NV ZIP: 89149 BUSINESS PHONE: 702-335-0356 MAIL ADDRESS: STREET 1: 7230 INDIAN CREEK LN STREET 2: STE 201 CITY: LAS VEGAS STATE: NV ZIP: 89149 FORMER COMPANY: FORMER CONFORMED NAME: UTEC, INC. DATE OF NAME CHANGE: 20080212 FORMER COMPANY: FORMER CONFORMED NAME: Lyon Capital Venture Corp. DATE OF NAME CHANGE: 20070111 10-K 1 tgro-20161231_10k.htm TIGER OIL AND ENERGY, INC., 10-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10K

(Mark One)

[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

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

For the transition period from to

Commission file number 333-141875

Tiger Oil and Energy, Inc.

(Exact name of registrant as specified in its charter)

	NEVADA	20-5936198
	State or other jurisdiction of	(I.R.S. Employer
	incorporation or organization	Identification No.)

7230 Indian Creek Ln. Ste. 201, Las Vegas, NV 89149

(Address of principal executive offices)

Registrant’s telephone number, including area code (702) 336-0356

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

Title of each class

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

(Title of class)

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

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.
[ ] Yes [x] No

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

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§ 229.405 of this chapter) is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.

[ ]

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

Large accelerated filer [ ]		Accelerated filer [ ]
Non-accelerated filer [ ] (Do not check if a smaller reporting company)		Smaller reporting company [x]

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

State the aggregate market value of the voting and non-voting common equity held by non-affiliates computed by reference to the price at which the common equity was last sold, or the average bid and asked price of such common equity, as of the last business day of the registrant’s most recently completed second fiscal quarter.

Note.—If a determination as to whether a particular person or entity is an affiliate cannot be made without involving unreasonable effort and expense, the aggregate market value of the common stock held by non-affiliates may be calculated on the basis of assumptions reasonable under the circumstances, provided that the assumptions are set forth in this Form.

(APPLICABLE ONLY TO CORPORATE REGISTRANTS)

Indicate the number of shares outstanding of each of the registrant’s classes of common stock, as of the latest practicable date. As of April 11, 2017 the Company had 37,105,062 issued and outstanding shares of its common stock and 22,013 of its preferred stock.

DOCUMENTS INCORPORATED BY REFERENCE

List hereunder the following documents if incorporated by reference and the Part of the Form 10-K (e.g., Part I, Part II, etc.) into which the document is incorporated: (1) Any annual report to security holders; (2) Any proxy or information statement; and (3) Any prospectus filed pursuant to Rule 424(b) or (c) under the Securities Act of 1933. The listed documents should be clearly described for identification purposes (e.g., annual report to security holders for fiscal year ended December 24, 1980).

Tiger Oil and Energy, Inc.

TABLE OF CONTENTS

FORWARD-LOOKING STATEMENTS	2

PART I	2
Item 1. Business.	3
Item 1A. Risk Factors	4
Item 1B. Unresolved Staff Comments.	4
Item 2 Properties.	4
Item 3. Legal Proceedings.	4
Item 4. Submission of Matters to a Vote of Security Holders.	4
PART II	4
Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities.	4
Item 6. Selected Financial Data.	4
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.	5
Item 7A. Quantitative and Qualitative Disclosures About Market Risk.	6
Item 8. Financial Statements and Supplementary Data.	6
Item 9. Changes in and Disagreements With Accountants on Accounting and Financial Disclosure.	6
Item 9A(T). Controls and Procedures.	7
Item 9B. Other Information.	8
PART III	8
Item 10. Directors, Executive Officers and Corporate Governance.	8
Item 11. Executive Compensation.	9
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters.	10
Item 13. Certain Relationships and Related Transactions, and Director Independence.	10
Item 14. Principal Accounting Fees and Services.	10
PART IV	12
Item 15. Exhibits, Financial Statement Schedules.	12
SIGNATURES	13

FORWARD-LOOKING STATEMENTS

Certain of the statements made or incorporated by reference in this Form 10-K, including those under “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” and elsewhere in this report, may constitute “forward-looking statements” within the meaning of, and subject to the protections of, Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”).

Forward-looking statements include statements with respect to our beliefs, plans, objectives, goals, targets, expectations, anticipations, assumptions, estimates, intentions and future performance, and involve known and unknown risks, uncertainties and other factors, many of which may be beyond our control, and which may cause the actual results, performance or achievements of the Company, or the commercial banking industry or economy generally, to be materially different from future results, performance or achievements expressed or implied by such forward-looking statements.

All statements other than statements of historical fact are statements that may be forward-looking statements. You can identify these forward-looking statements through our use of words such as “may,” “will,” “anticipate,” “assume,” “should,” “indicate,” “would,” “believe,” “contemplate,” “expect,” “estimate,” “continue,” “plan,” “target,” “point to,” “project,” “predict,” “could,” “intend,” “target,” “potential,” and other similar words and expressions of the future or otherwise regarding the outlook for the Company’s future business and financial performance.

All written or oral forward-looking statements that are made by or are attributable to us are expressly qualified in their entirety by this cautionary notice. You should not place undue reliance on any forward-looking statements, since those statements speak only as of the date that they are made. We have no obligation and do not undertake to publicly update, revise or correct any of the forward-looking statements after the date of this report, or after the respective dates on which such statements otherwise are made, whether as a result of new information, future events or otherwise, except as may otherwise be required by law.

PART I

Item 1. Business.

General Information

Except for statements of historical fact, certain information in this document contains “forward-looking statements” that involve substantial risks and uncertainties. You can identify these statements by forward-looking words such as “anticipate,” “believe,” “could,” “estimate,” “expect,” “intend,” “may,” “should,” “will,” ‘would,” or similar words. The statements that contain these or similar words should be read carefully because these statements discuss our future expectations, contain projections of our future results of operations, or of our financial position, or state other “forward-looking” information. Tiger Oil and Energy, Inc. (“The Company” or “TGRO”) believes that it is important to communicate our future expectations to our investors. However, there may be events in the future that we are not able to accurately predict or control. Further, we urge you to be cautious of the forward-looking statements that are contained in this Form 10-K because they involve risks, uncertainties and other factors affecting our operations, market growth, service, products and licenses. These factors may cause our actual results to and achievements, whether expressed or implied, to differ materially from the expectations we describe in our forward-looking statements. The occurrence of any of these events could have a material adverse effect on our business, results of operations and financial position.

Corporate History

Tiger Oil and Energy, Inc.,( formerly UTEC INC., formerly Lyon Capital Venture Corp., is a Nevada corporation organized on November 8, 1993 as a “For Profit” corporation for the purpose of engaging in any lawful activity. The Company was in the development stage through December 31, 2006. The year ended December 31, 2007, is the first year during which the Company is considered an operating company and was no longer considered in a development stage. On January 10, 2007, the Company purchased 100% of the shares of UTEC Corporation, Inc. from Energetic Systems Inc. LLC, for a total consideration of 22,500,000 of the Company’s par value $0.001 common shares and 20,000 of the Company’s par value $0.001 preferred shares. Each share of our preferred stock entitles the owner to 2,500 votes. Shares of our preferred shares can be converted to two common for one preferred. The Company also issued 2,525,000 common shares in finder’s fees.

Business of Issuer

On October 27, 2010 we entered into a co-development agreement with Black Hawk Exploration, (BHWX), in which we, after an investment of $400,000 by the Company in a new well in Black Hawk’s Cowley County lease, we will earn a 40% working interest in the # 1 Baker well, BHWX will receive a 50% interest in the new well and TGRO will have the right to participate in the nine-well rework program at the Cowley Prospect. BHWX will receive a 20% interest in any other new well TGRO drills on Black Hawk’s current or future Cowley County, Kansas leases and Black Hawk has the option to invest in each additional new well drilled by TGRO on a prorated basis up to an additional 30%.

On November 29, 2010, the Company expanded its original agreement and entered into a co-development agreement with Black Hawk Exploration covering approximately 2,553 acres of oil and gas leases in Cowley County, Kansas. BHWX owns 100% of the leases within the Prospect Area and has an undivided 81.5% working interest in and to the oil and gas leases and their previous 10 shut-in oil and gas wells.

The joint agreement includes in one shut-in oil/gas well, the #1 Baker, located on the Keith Baker lease. Also subject to joint development is a 100% interest in 9 other oil wells previously shut-in. The Company’s program calls for re-working all 10 locations directly or in joint venture with Black Hawk and returning all of them to cash flow production.

On February 4, 2011, we retained International IR Inc. (IRR) to provide media services. IIR is a strategic consulting firm that works primarily with emerging growth companies in the resource sector. IIR will focus on providing multiple information platforms to TGRO’s shareholders and advise as well as negotiate on behalf of the Company, acquisition, exploration and joint venture agreements and strategies.

On February 9th, 2011, we acquired a 100% interest in three Oil and Gas leases totaling 400 acres in Southern Kansas, comprised of three historically productive properties. Our Geologist has reviewed the Holman #2, #3, #4, and #5; the Adams #1 and the Glasse wells commonly known as the Wise #1 and Roberts #1 and have recommended a seven-well exploration and production study. All the leases acquired by the parties covering lands within the prospect area are owned 100% by TGRO with an undivided eighty-one and one-half percent (81.5%) working interest in the oil and gas leases described. The Company issued a Note and 250,000 shares of its common stock in the acquisition. We will require an investment of $400,000 to initiate putting these wells back into production. Management believes this can be accomplished and is considering various options to acquire this funding, but has not yet entered into an agreement to do so.

On May 4, 2014, we acquired 30% WI in the DeFore and Stalnaker leases in Cowley County from a Company affiliated with the President of our Company. The Company paid $402,000 for their share of drilling two wells on the leases. Both wells went online and began production in 2015.

The Company will continue to evaluate shut in wells in the states of Kansas and Oklahoma with intention of putting historically productive wells back into production at the least cost. We will then need to enter into private placement agreements to fund the programs.

Indemnification of Directors and Officers

Our bylaws contain provisions which require that the company indemnify its officers, directors, employees and agents, in substantially the same language as Section 78.7502 of the Nevada Revised Statutes. Article 12 of the Company’s Articles of Incorporation provides for the Company’s ability to indemnify its officers, directors, employees and agents, subject to the limitations provided in Nevada Revised Statutes 78.7502, for expenses actually and reasonably incurred. No indemnification shall be made if the proposed party has been adjudged to be liable to the company or where the matter was settled without court approval. Indemnification must be made upon a determination by a majority of the uninterested Board, and if not available, by the shareholders or by a court of competent jurisdiction.

Item 1A. Risk Factors.

Not Applicable

Item 1B. Unresolved Staff Comments.

None

Item 2. Properties.

Our offices are located at 7230 Indian Creek Lane, Ste 201, Las Vegas, NV 89149. The facilities are on a month to month basis at a cost of $500 per month. Specific direct expenses incurred such as telephone and secretarial services are charged back to the Company at cost.

Item 3. Legal Proceedings.

During the year ended December 31, 2015 the Company became party to a legal action brought about by an unrelated third-party individual, wherein the plaintiff alleged the Company “participated and/or conspired in a scheme to disseminate spam emails” which were misleading in order to encourage individuals to purchase shares the Company’s common stock at an artificial and/or inflated stock price. On October 10, 2016, the Company reached a settlement agreement whereby the Company agreed to pay $11,000 in exchange for a general release of all claims against the Company. As of December 31, 2016, the case is considered fully resolved and closed.

Item 4. Submission of Matters to a Vote of Security Holders.

None

PART II

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities.

The Company’s common stock trades on the Over-The-Counter Bulletin Board (OTC:BB) under the symbol TGRO. The following table shows the high and low trading prices for the past two years.

	2016				2015
	High		Low		High		Low
Qtr 1		0.018		0.007		0.0598		0.025
Qtr 2		0.01		0.007		0.0314		0.019
Qtr 3		0.025		0.007		0.025		0.013
Qtr 4		0.021		0.015		0.025		0.008

We did not make any dividend payments during the fiscal years ended December 31, 2016 or 2015 and have no plans to pay dividends in the foreseeable future. We did not repurchase any shares of our common stock during the fiscal year ended December 31, 2016 or 2015.

Transfer Agent: Quicksilver Stock Transfer LLC, 2258 Green Mountain Ct. Las Vegas Nevada 89135

The Company did not make any repurchases of its securities during the year ended December 31, 2016.

Item 6. Selected Financial Data.

Not Applicable

Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.

This 10K contains certain forward-looking statements and our future operating results could differ materially from those discussed herein. Such forward-looking statements involve known and unknown risks, uncertainties and other factors which may cause our actual results, performance or achievements to be materially different from any future results, performance or achievements expressed or implied by such forward-looking statements. Given these uncertainties, readers are cautioned not to place undue reliance on such forward-looking statements. We disclaim any obligation to update any such factors or to announce publicly the results of any revisions of the forward -looking statements contained herein to reflect future events or developments.

Going Concern

The future of our company is dependent upon its ability to obtain financing and upon future profitable operations from the sale of products and services through our websites. Management has plans to seek additional capital through a private placement and public offering of its common stock, if necessary. Our auditors have expressed a going concern opinion because uncertainties raise doubts about the Issuers ability to continue as a going concern.

Background

Corporate Overview

Unless otherwise indicated, in this 10K, references to “we,” “our,” “us,” the “Company,” “TGRO” refer to Tiger Oil and Energy, Inc., a Nevada corporation (formerly UTEC, Inc.) and Jett Rink which became a wholly owned subsidiary October 29, 2010 after the closing of the voluntary share exchange transaction described above.. Future plans include the exploration, development and production of oil and gas in the United States. Our current focus is to secure $1,400,000 in financing to increase our holdings and develop our current oil and gas assets over the next twelve months.

On October 29, 2010 the Company changed its corporate name to Tiger Oil and Energy, Inc.

On October 27, 2010 Tiger Oil and Energy, Inc. (TGRO) entered into a co-development agreement with Black Hawk Exploration, in which the Company, after an investment of $400,000 by TGRO in a new well in Black Hawk’s Cowley County lease, the Company will earn a 40% working interest in the # 1 Baker well, BHWX will receive a 50% interest in the new well and TGRO will have the right to participate in the 9 well rework program at the Cowley Prospect. BHWX will receive a 20% interest in any other new well TGRO drills on Black Hawk’s current or future Cowley County, Kansas leases and Black Hawk has the option to invest in each additional new well drilled by TGRO on a prorated basis up to an additional 30%.

On November 29, 2010 the Company expanded its original agreement and entered into a joint venture agreement with Black Hawk Exploration covering approximately 2,553 acres of oil and gas leases in Cowley County, Kansas. BHWX owns 100% of the leases within the Prospect Area and has an undivided 81.5% working interest in and to the oil and gas leases and their previous 10 shut-in oil and gas wells.

Our current focus is to secure $1,400,000 in financing to increase our holdings and develop our current oil and gas assets over the next twelve months.

Revenues

Revenues from continuing operations for the years ended December 31, 2016 and 2015 were $-0- and $15,008 respectively. In 2009, as part of the sale of the legacy business the Company divested all assets that generated revenue. During the 2015 fiscal year the Company once again began recognizing revenues on the sale of oil and gas. In 2016 the Company reduced activity with its oil and gas properties, due to the low prices of oil and gas. The Company anticipates increasing production once oil and gas prices rebound to historical norms.

Operating Expenses

Operating expenses for the year ended December 31, 2016 and 2015 were $110,590 and $490,655, respectively. Of these totals, general and administrative expenses amounted to $36,840 and $38,365, respectively; legal and professional expenses totaled $68,882 and $46,059, respectively; lease operating expenses of $4,079 and $689; and accretion expense totaled $789 and $715, respectively. Additionally, in the 2015 fiscal year the Company recorded an impairment of its oil and gas properties in the amount of $404,837.

Other Income (Expenses)

During the years ended December 31, 2016 and 2015 the Company recognized interest expense in the amount of $35,005 and $33,741, respectively. Additionally, in 2016 the Company recognized a gain on settlement of debt totaling $58,684.

Net Loss

For the years ended December 31, 2016 and 2015, the Company recognized net losses in the amounts of $86,911 and $509,388, respectively.

Liabilities

The Company’s liabilities primarily consist of current amounts payable or accrued to trade creditors. At December 31, 2016 and 2015 the Company holds notes payable with outstanding balances of $-0- and $5,200, respectively, notes payable to related parties totaling $61,500 and $35,000, respectively, and convertible note payable with a net balance of $600,000, respectively.

Liquidity and Capital Resources

At December 31, 2016 the Company had negative working capital of $809,352, compared to negative working capital of $723,931 in 2015.

As of December 31, 2016, the Company had $472 in current assets, consisting of $272 in cash, and deposits of $200, compared to $15,247 in current assets at December 31, 2015, which consisted of cash of $15,047 and deposits of $200. Total liabilities at December 31, 2016 totaled $821,203 compared to $750,712 at December 31, 2015. The current liabilities at December 31, 2016 consisted of accounts payable and accrued expenses of $114,380, accounts payable to related parties of $33,000, notes payable of $61,500, and convertible notes payable of $600,000. At December 31, 2015 the current liabilities consisted of accounts payable and accrued expenses of $82,978, accounts payable to related parties of $16,000, notes payable of $40,200 and convertible notes payable of $600,000.

The Company estimates that it will require $400,000 to accomplish its short-term goal of bringing its wells back into production and the company's sole source of liquidity to this point has been through the sale of common stock. Such funding that is required to maintain liquidity will come in the form of equity sales of common stock.

Item 7A. Quantitative and Qualitative Disclosures About Market Risk.

Not applicable.

Item 8. Financial Statements and Supplementary Data.

The Financial Statements are included at the end of the signature page.

Item 9. Changes in and Disagreements With Accountants on Accounting and Financial Disclosure.

None.

Item 9A(T). Controls and Procedures.

As of December 31, 2016, under the direction of the Chief Executive Officer and Chief Financial Officer, the Company evaluated the effectiveness of the design and operation of our disclosure controls and procedures, as defined in Rule 13a — 15(e) under the Securities Exchange Act of 1934, as amended. Based on the evaluation of these controls and procedures required by paragraph (b) of Sec. 240.13a-15 or 240.15d-15 the disclosure controls and procedures have been found to be not effective.

The Company maintains a set of disclosure controls and procedures designed to ensure that information required to be disclosed by us in our reports filed under the securities Exchange Act, is recorded, processed, summarized, and reported within the time periods specified by the SEC’s rules and forms. Disclosure controls are also designed with the objective of ensuring that this information is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure.

Evaluation of Internal Control Over Financial Reporting

Management conducted an evaluation of the effectiveness of the Company’s internal control over financial reporting as of Dec. 31, 2016. In making this assessment, management used the criteria established in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission, or COSO. The COSO framework summarizes each of the components of a company’s internal control system, including (i) the control environment, (ii) risk assessment, (iii) control activities, (iv) information and communication, and (v) monitoring. In management’s assessment of the effectiveness of internal control over financial reporting (as defined in Exchange Act Rule 13a-15(f)) as required by Exchange Act Rule 13a-15(c), our management concluded as of the end of the fiscal year covered by this Annual Report on Form 10-K that our internal control over financial reporting has not been effective.

As defined by Auditing Standard No. 5, “An Audit of Internal Control Over Financial Reporting that is Integrated with an Audit of Financial Statements and Related Independence Rule and Conforming Amendments,” established by the Public Company Accounting Oversight Board ("PCAOB"), a material weakness is a deficiency or combination of deficiencies that results more than a remote likelihood that a material misstatement of annual or interim financial statements will not be prevented or detected. In connection with the assessment described above, management identified the following control deficiencies that represent material weaknesses as of December 31, 2016:

i)	Lack of segregation of duties. At this time, our resources and size prevent us from being able to employ sufficient resources to enable us to have adequate segregation of duties within our internal control system. Management will periodically reevaluate this situation.

ii)

Lack of an independent audit committee. Although we have an audit committee it is not comprised solely of independent directors. We may establish an audit committee comprised solely of independent directors when we have sufficient capital resources and working capital to attract qualified independent directors and to maintain such a committee.

iii)	Insufficient number of independent directors. At the present time, our Board of Directors does not consist of a majority of independent directors, a factor that is counter to corporate governance practices as set forth by the rules of various stock exchanges.

Our management determined that these deficiencies constituted material weaknesses. Due to a lack of financial resources, we are not able to, and do not intend to, immediately take any action to remediate these material weaknesses. We will not be able to do so until we acquire sufficient financing to do so. We will implement further controls as circumstances, cash flow, and working capital permit. Notwithstanding the assessment that our ICFR was not effective and that there were material weaknesses as identified in this report, we believe that our financial statements fairly present our financial position, results of operations and cash flows for the years covered thereby in all material respects.

Changes in Internal Control over Financial Reporting

There was no change in our internal controls over financial reporting that occurred during the period covered by this report, that has materially affected, or is reasonable likely to materially affect, our internal controls over financial reporting.

The Company has not taken any steps at this time to address these weaknesses but expects to formulate a plan before fiscal year ending December 31, 2016.

Item 9B. Other Information.

None

PART III

Item 10. Directors, Executive Officers and Corporate Governance.

The names, ages, and respective positions of the directors, officers, and significant employees of the Company are set forth below.

Name	Position Held with the Company	Age		Date First Elected or Appointed
Kenneth Liebscher	President and Director		74	July 1, 2006 to present
Howard Bouch	Chief Financial Officer and Director Secretary Treasurer		72	January 12, 2007 to present

Kenneth B. Liebscher, President, CEO, Director and Chairman.

Ken Liebscher is a 74-year-old international businessman with 40 years of securities and executive management experience. Mr. Liebscher is a graduate of St. George’s School, Vancouver, B.C. and also attended the University of British Columbia. In 22 years with the world’s largest dental products manufacturer, Dentsply International Inc., Mr. Liebscher held several positions culminating as the Manager of their West Coast Division, headquartered in San Francisco California. Mr. Liebscher was recruited by a major Europe based competitor, Ivoclar Liechtenstein to lead their entry into the North American market and, within two years, became Executive Vice President of Sales and Marketing and helped expand this company’s sales to $300,000,000 US before retiring.

Mr. Liebscher became a director of a publicly held company called E.T.C. Industries Ltd. in 1992 and became President of its wholly owned subsidiary, THE ELECTRIC CAR COMPANY and, in 1994, led a team that developed the MI 6 prototype electric car from the ground up. Mr. Liebscher has served on the Board of Directors of Belmont Resources Inc., listed on the TSX Venture Exchange (BEA.V) from 1992 to October, 2009.

Howard Bouch, CFO and Director

Howard Bouch, age 72, is a Private Practice Chartered Accountant with over 38 years of Public and Private international experience. Mr. Bouch originally qualified as a Chartered Accountant (English and Wales Institute) in 1968. Mr. Bouch joined Deloitte & Co, Lusaka, Zambia from 1970 - 1972. Mr. Bouch joined Anglo American Corp, Zambia working as Head Office Chief Accountant for Nchanga Consolidated Copper Mines (world’s 2nd largest) from 1972 - 1976. In 1976 Mr. Bouch returned to the UK and joined Babcock and Wilcox, Engineers, Nottinghamshire, England as Chief Accountant for one of their subsidiaries. Mr. Bouch was Chief Accountant of a private building firm in Cumbria, England from 1978 - 1984. In 1984 Mr. Howard Bouch established a Private Practice as a Chartered Accountant and continues to provide professional services to Cumbrian firms to the present. Mr. Bouch is a Director of Viavid Broadcasting Inc., a fully reporting, US Public Company, trading on the Pink Sheets under the symbol (VVDB) and Director and CFO of Universal Potash Corp. (UPCO).

The Officers and Directors have not been involved in legal proceedings that impair their ability to perform their duties as Officers and Directors.

Code of Ethics

Effective April 1, 2008, our company’s Board of Directors adopted a Code of Business Conduct and Ethics that applies to existing and all new, among other persons, our company’s CEO, CFO and secretary (being our principal executive officer, principal financial officer and principal accounting officer), as well as persons performing similar functions. As adopted, our Code of Business Conduct and Ethics sets forth written standards that are 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 we file with, or submit to, the Securities and Exchange Commission and in other public communications made by us;

Compliance with applicable governmental laws, rules and regulations;

The prompt internal reporting of violations of the Code of Business Conduct and Ethics to an appropriate person or persons identified in the Code of Business Conduct and Ethics; and

Accountability for adherence to the Code of Business Conduct and Ethics. Our Code of Business Conduct and Ethics requires, among other things, that all of our company’s Senior Officers commit to timely, accurate and consistent disclosure of information; that they maintain confidential information; and that they act with honesty and integrity.

In addition, our Code of Business Conduct and Ethics emphasizes that all employees, and particularly Senior Officers, have a responsibility for maintaining financial integrity within our company, consistent with generally accepted accounting principles, and federal and state securities laws. Any Senior Officer who becomes aware of any incidents involving financial or accounting manipulation or other irregularities, whether by witnessing the incident or being told of it, must report it to our company. Any failure to report such inappropriate or irregular conduct of others is to be treated as a severe disciplinary matter. It is against our company policy to retaliate against any individual who reports in good faith the violation or potential violation of our company’s Code of Business Conduct and Ethics by another.

Our Code of Business Conduct and Ethics was filed with the Securities and Exchange Commission on May 15, 2008 as an Exhibit to our Form10. We will provide a copy of the Code of Business Conduct and Ethics to any person without charge, upon request. Requests can be sent to: Tiger Oil and Energy, Inc, 7230 Indian Creek Ln., Ste 201, Las Vegas, NV 89149

Item 11. Executive Compensation.

The following charts include compensation and options received by all Officers and Directors of the Company.

Officers and Directors

Name and principal position	Year		Salary ($)		Bonus ($)		Stock Awards ($)		Option Awards		Non- Equity Incentive Plan Compensation ($)		Nonqualified Deferred Compensation Earnings ($)		All Other Compensation ($)		Totals ($)
Kenneth Liebscher		2016		0		0		0		0		0		0		6,000		6,000
		2015		0		0		0		0		0		0		12,000		12,000
Howard Bouch		2016		0		0		0		0		0		0		0		0
		2015		0		0		0		0		0		0		0		0

OPTIONS

There are no options granted.

For the year ended December 31, 2016 and 2015 share-based compensation expense of $-0- and $-0- was recognized, respectively.

There are no annuity, pension or retirement benefits proposed to be paid to officers, directors, or employees of the corporation in the event of retirement at normal retirement date pursuant to any presently existing plan provided or contributed to by the corporation or any of its subsidiaries.

Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters.

The owners of 5% or more of the Shares, as well as the officers and directors who own Shares as of December 31, 2016, are set forth in the following chart:

Title of Class	Name of Beneficial Owner	Amount and Nature of Beneficial Owner		Percent of Class
Preferred Stock	Kenneth Liebscher, President/CEO And Director		20,000		47.6	%
Preferred Stock	Howard Bouch, CFO and Director		Nil		0	%
Common Stock	Kenneth Liebscher, President/CEO and Director		2,000,000		5	%
Common Stock	All Officers and Directors as a group of Common Stock		2,000,000		5	%

Item 13. Certain Relationships and Related Transactions, and Director Independence.

Other than as set forth in this Item 7, there are no relationships, transactions, or proposed transactions to which the registrant was or is to be a party, in which any of the named persons set forth in Item 404 of Regulation SK had or is to have a direct or indirect material interest.

From time to time the Company enters into arrangements for the provision of services from one or more of its Directors, or companies in which its Directors have a financial interest.

The company has chosen to adopt NASD’s definition of independent director. Under such definition, Howard Bouch qualifies as an independent director.

Item 14. Principal Accounting Fees and Services.

On November 2, 2009, the accounting firm of Sadler, Gibb & Associates, LLC was engaged as the Registrant’s independent registered public account firm.

	2016		2015
Audit Fees	$	9,500	$	9,500
Audit Related Fees		—		—
Tax Fees		—		—
All Other Fees		—		—
Total	$	9,500	$	9,500

Services rendered by Sadler Gibb & Associates for the year ended December 31, 2016 in connection with fees presented above were as follows:

● Audit fees consist of fees for professional services provided in connection with the audit of our consolidated financial statements, the review of our quarterly consolidated financial statements and the audit of the effectiveness of our internal control over financial reporting.

On January 1, 2017 the accounting firm of Sadler, Gibb & Associates resigned as the Company’s independent registered public accounting firm, due to partner rotation mandates. On April 10, 2017 the Company engaged Pinaki & Associates, LLC as its independent registered public accounting firm. Pinaki and Associates did not perform any audit services, audit-related services, tax services, or other services for the Company during the years ended December 31, 2016 and 2015.

POLICY ON AUDIT COMMITTEE

Among its other duties, the Audit Committee is solely responsible for the appointment, compensation and oversight of the audit and permissible non-audit services provided by our independent registered public accounting firm. Pursuant to the Audit Committee’s charter, the Chairman of the Audit Committee has been delegated responsibility to review and pre-approve audit and permissible non-audit services to be provided by our independent registered public accounting firm. The Chairman of the Audit Committee then reports such pre-approvals to the full Audit Committee at its next regularly scheduled meeting. In accordance with this pre-approval policy, management communicates, on an ongoing basis, specific projects and categories of service for which the advance approval of the Audit Committee is requested. The Audit Committee Chairman reviews these requests and advises management whether the engagement of the independent registered public accounting firm is approved. On a periodic basis, management subsequently reports to the Audit Committee regarding the actual spending for particular projects and in connection with categories of services.

Management is responsible for the financial reporting process, including the system of internal controls, and for the preparation of consolidated financial statements in accordance with accounting principles generally accepted in the United States. The Company’s independent registered public accounting firm is responsible for auditing those financial statements. The members of the Audit Committee are not professionally engaged in the practice of accounting or auditing and their functions are not intended to duplicate or to certify the activities of management and the independent registered public accounting firm. Rather, the members of the Audit Committee rely, without independent verification, on the information provided to them and on the representations made by management and the independent registered public accounting firm.

Notwithstanding anything to the contrary set forth in any of the Company’s previous or future filings under the Securities Act of 1933, as amended, or the Securities Exchange Act of 1934, as amended, that might incorporate filings made by the Company, including this proxy statement, in whole or in part, the following Audit Committee Report shall not be deemed to be “soliciting material” or to be incorporated by reference into any prior or future filings made by the Company.

We have reviewed and discussed with management the Company’s audited consolidated financial statements as of and for the year ended December 31, 2016.

Based on the reviews and discussions with the audit group, we have recommended to the Board that the audited consolidated financial statements referred to above be included in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2016.

Audit Chairman

Howard Bouch

PART IV

Item 15. Exhibits, Financial Statement Schedules.

Exhibits:


Exhibit No.	Document	Location

3.1	Articles of Incorporation	Previously filed*

3.2	Articles of Amendment – Allwest	Previously filed*

3.3	Articles of Amendment – Lyons Capital	Previously filed*

3.4	Articles of Amendment – UTEC	Previously filed*

3.5	Articles of Amendment – Share Increase	Previously filed**

3.6	Bylaws	Previously filed* (As Exhibit 3.5)

14.1	Code of Business Conduct and Ethics	Previously filed*

31.1	Rule 13a-41(a)/15d-14(a) Certificates

31.2	Rule 13a-41(a)/15d-14(a) Certificates

32.1	Section 1350 Certifications

32.2	Section 1350 Certifications

*Previously filed on May 14, 2008 as exhibits to Form 10-12G.

SIGNATURES

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

Tiger Oil and Energy, Inc

*/s/ Kenneth B Liebscher*		*/s/ Howard Bouch*
Kenneth B. Liebscher, Director & CEO		Howard Bouch, CFO

Date April 14, 2017

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed by the following persons on behalf of the registrant and in the capacities and on the dates indicated.


*/s/ Kenneth Liebscher*		April 14, 2017
Kenneth Liebscher,		Date
President, CEO, Director
*/s/ Howard Bouch*		April 14, 2017
Secretary, Treasurer, CFO Director		Date

TIGER OIL AND ENERGY, INC.

AUDIT REPORT OF INDEPENDENT ACCOUNTANTS
AND
CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2016 and 2015

	Page(s)
Report of Independent Registered Public Accounting Firm		F-1

Consolidated Balance Sheets as of December 31, 2016 and December 31, 2015		F-3

Consolidated Statements of Operations for the years ended December 31, 2016 and 2015		F-4

Consolidated Statements of Stockholders Deficit		F-5

Consolidated Statements of Cash Flows for the years ended December 31, 2016 and 2015		F-6

Notes to Consolidated Financial Statements		F-7

Pinaki & Associates LLC

Certified Public Accountants

625 Barksdale Rd., Ste# 113

Newark, DE 19711

Phone: 408-896-4405 | pmohapatra@pinakiassociates.com

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Board of Directors

Tiger Oil And Energy Inc.

7230 Indian Creek Ln,

Suite 201

Las Vegas, NV 89149

We have audited the accompanying consolidated balance sheets of Tiger Oil And Energy Inc. as of December 31, 2016 and the related consolidated statements of income, stockholders’ equity and cash flows for the year ended December 31, 2016. These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.

We conducted our audits in accordance with standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Tiger Oil And Energy Inc. as of December 31, 2016 and the related consolidated statements of income, stockholders’ equity and cash flows for the year ended December 31, 2016 in conformity with accounting principles generally accepted in the United States of America.

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 suffered recurring losses from operations that raises a substantial doubt about its ability to continue as a going concern. The financial statements do not include any adjustments that might result from the outcome of this uncertainty.

s/d

Pinaki & Associates, LLC Newark, DE

April 12, 2017

F-1

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors

Tiger Oil and Energy, Inc.

We have audited the accompanying consolidated balance sheet of Tiger Oil and Energy, Inc. (the Company) as of December 31, 2015 and the related consolidated statements of operations, stockholders’ equity and cash flows for the year then ended. These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.

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

In our opinion the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Tiger Oil and Energy, Inc. as of December 31, 2015, and the results of their operations and cash flows for the year then ended, in conformity with U.S. generally accepted accounting principles.

The accompanying consolidated financial statements have been prepared assuming that the Company will continue as a going concern. As discussed in Note 2 to the consolidated financial statements, the Company has suffered net losses and has accumulated a significant deficit. These factors raise substantial doubt about its ability to continue as a going concern. The consolidated financial statements do not include any adjustments that might result from the outcome of this uncertainty.

/s/ Sadler, Gibb & Associates, LLC

Salt Lake City, UT

April 13, 2016

F-2

TIGER OIL AND ENERGY, INC.
Consolidated Balance Sheets

	December 31,
	2016			2015

ASSETS

CURRENT ASSETS
Cash and cash equivalents	$	272		$	15,047
Prepaid expenses and deposits		200			200

Total Current Assets		472			15,247

OTHER ASSETS
Oil and gas properties, net (full cost method)		—			—

TOTAL ASSETS	$	472		$	15,247

LIABILITIES AND STOCKHOLDERS' DEFICIT

CURRENT LIABILITIES
Accounts payable and accrued expenses	$	114,380		$	82,978
Accounts payable - related party		33,000			16,000
Notes payable		—			5,200
Notes payable - related party		61,500			35,000
Convertible notes payable		600,000			600,000

Total Current Liabilities		808,880			739,178

LONG-TERM LIABILITIES
Asset retirement obligation		12,323			11,534

Total Long-Term Liabilities		12,323			11,534

TOTAL LIABILITIES		821,203			750,712

STOCKHOLDERS' DEFICIT
Preferred stock - 1,000,000 shares authorized,
$0.001 par value; 42,013 issued and outstanding		42			42
Common stock - 74,000,000 shares authorized,
$0.001 par value; 42,728,159 issued and outstanding		42,728			42,728
Additional paid-in capital		4,676,821			4,675,176
Accumulated deficit		(5,540,322	)		(5,453,411	)

Total Stockholders' Deficit		(820,731	)		(735,465	)

TOTAL LIABILITIES AND STOCKHOLDERS'
DEFICIT	$	472		$	15,247


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

F-3

TIGER OIL AND ENERGY, INC.
Consolidated Statements of Operations


	For the Years Ended
	December 31,
	2016			2015

REVENUES	$	—		$	15,008

OPERATING EXPENSES
Lease operating expense		4,079			679
Accretion expense		789			715
Legal and professional		68,882			46,059
Impairment of oil and gas properties		—			404,837
General and administrative		36,840			38,365

Total Operating Expenses		110,590			490,655

LOSS FROM OPERATIONS		(110,590	)		(475,647	)

OTHER INCOME (EXPENSE)
Interest expense		(35,005	)		(33,741	)
Gain on settlement of debt		58,684			—

Total Other Income (Expense)		23,679			(33,741	)

LOSS BEFORE TAXES		(86,911	)		(509,388	)
Provision for income taxes		—			—

NET LOSS	$	(86,911	)	$	(509,388	)

BASIC AND DILUTED LOSS PER SHARE	$	(0.00	)	$	(0.01	)

BASIC AND DILUTED WEIGHTED
AVERAGE NUMBER OF SHARES
OUTSTANDING		42,728,159			42,728,159

The accompanying notes are a integral part of these consolidated financials statements.

F-4

TIGER OIL AND ENERGY, INC.
Consolidated Statement of Stockholders' Deficit


									Additional
	Preferred Stock				Common Stock				Paid-In		Accumulated
	Shares		Amount		Shares		Amount		Capital		Deficit			Total

Balance, December 31, 2013		42,013	$	42		42,728,159	$	42,728	$	4,275,176	$	(4,457,314	)	$	(139,368	)

Beneficial conversion on
convertible note payable		—		—		—		—		400,000		—			400,000

Net loss for the year ended
December 31, 2014		—		—		—		—		—		(486,709	)		(486,709	)

Balance, December 31, 2014		42,013		42		42,728,159		42,728		4,675,176		(4,944,023	)		(226,077	)

Net loss for the year ended
December 31, 2015		—		—		—		—		—		(509,388	)		(509,388	)

Balance, December 31, 2015		42,013		42		42,728,159		42,728		4,675,176		(5,453,411	)		(735,465	)

Settlement of related-party debt		—		—		—		—		1,645		—			1,645

Net loss for the year ended
December 31, 2016		—		—		—		—		—		(86,911	)		(86,911	)

Balance, December 31, 2016		42,013	$	42		42,728,159	$	42,728	$	4,676,821	$	(5,540,322	)	$	(820,731	)

F-5

TIGER OIL AND ENERGY, INC.
Consolidated Statements of Cash Flows

	For the Years Ended
	December 31,
	2016			2015
OPERATING ACTIVITIES
Net loss	$	(86,911	)	$	(509,388	)
Adjustments to Reconcile Net Loss to Net
Cash Used by Operating Activities:
Depreciation, amortization and accretion expense		789			715
Gain on property settlement		(58,684	)		—
Impairment of oil and gas properties		—			404,837
Amortization of debt discount		—			3,288
Changes in operating assets and liabilities:
Accounts payable and accrued liabilities		32,847			48,569
Accounts payable - related party		17,000			10,000

Net Cash Used in Operating Activities		(94,959	)		(41,979	)

INVESTING ACTIVITIES
Proceeds from property settlement		58,684			—

Net Cash Used in Investing Activities		58,684			—

FINANCING ACTIVITIES
Proceeds from notes payable - related party		66,500			40,000
Repayments on note payable		(5,000	)		—
Repayments of notes payable - related party		(40,000	)		—

Net Cash Provided by Financing Activities		21,500			40,000

NET INCREASE (DECREASE) IN CASH	$	(14,775	)	$	(1,979	)
CASH AT BEGINNING OF PERIOD		15,047			17,026

CASH AT END OF PERIOD	$	272		$	15,047

SUPPLEMENTAL DISCLOSURES OF
CASH FLOW INFORMATION

CASH PAID FOR:
Income taxes	$	—		$	—
Interest		—			—

NON-CASH FINANCING AND INVESTING ACTIVITIES:
Beneficial conversion on convertible note	$	—		$	—
Asset retirement obligations	$	—		$	—

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

F-6

TIGER OIL AND ENERGY, INC.

Notes to Consolidated Financial Statements

December 31, 2016 and 2015

NOTE 1 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Business Activity

Tiger Oil and Energy, Inc., formerly UTeC, Inc., is a Nevada corporation organized on November 8, 1993 as a “For Profit” corporation for the purpose of engaging in any lawful activity. On January 10, 2007, the Company purchased 100% of the shares of UTeC Corporation, Inc. In 2007, the Company licensed technology covering the use of cold plasma oxidizer technology for the destruction of solid and liquid hazardous chemicals and biologicals. During 2007 and 2008, the Company worked to validate the technology and prepare a business plan for its commercialization.

In April 2009, the Company divested its commercial explosives development, analysis, testing and manufacturing business to eliminate the need to inject new capital into the Company to support this business, and concentrate on raising the funds necessary to commercialize its hazardous waste destruction business. At this time, the Company re-entered the development stage.

Prior to the divestiture, the Company’s business was to offer state of the art testing and analysis to clients worldwide. The Company operated a chemical research and development laboratory near Riverton, Kansas, which specialized in commercial explosives development and analysis. The Company also operated a destructive test facility near Hallowell, Kansas, which specialized in determining the detonating characteristics of commercial explosives.

On October 1, 2009 the Company entered into an agreement to purchase 100% of the outstanding shares of C2R Energy Commodities, Inc., a Nevada corporation, in exchange for 4,050,000 shares of the Company’s restricted common stock. The Company entered into this agreement due primarily to the fact that C2R owned certain intellectual property that the Company wished to acquire.

On October 29, 2010, the Company acquired all of the membership interest in Jett Rink Oil, LLC (“Jett Rink”) in exchange for 10,000,000 shares of the Company’s Common Stock. Jett Rink is involved in the business relating to the exploration, development and production of oil and gas in the United States. At the closing of the Exchange Agreement, Jett Rink became a wholly-owned subsidiary of the Company and the Company acquired the business and operations of Jett Rink.

Basis of Presentation

The accompanying audited consolidated financial statements and related notes include the activity of the Company and its two wholly-owned subsidiaries, C2R Energy Commodities, Inc. and Jett Rink Oil, LLC and have been prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”) and with the rules and regulations of the United States Securities and Exchange Commission (“SEC”) to Form 10-K. All inter-company balances and transactions have been eliminated.

Reclassification

Certain amounts in the prior period financial statements have been reclassified to conform to the current period presentation. These reclassifications had no effect on reported losses.

F-7

TIGER OIL AND ENERGY, INC.

Notes to Consolidated Financial Statements

December 31, 2016 and 2015

NOTE 1 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

Consolidation

The accompanying consolidated financial statements included all of the accounts of the Company and its wholly-owned subsidiaries, C2R, Inc., a Nevada Corporation, and Jett Rink Oil, LLC, a Kansas Limited Liability Company. All intercompany transactions have been eliminated.

Accounting Method

The Company’s financial statements are prepared using the accrual method of accounting. The Company has elected a December 31 year-end.

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

Cash and Cash Equivalents

For purposes of the Statement of Cash Flows, the Company considers all highly liquid instruments purchased with a maturity of three months or less to be cash equivalents to the extent the funds are not being held for investment purposes. The Company at times may maintain a cash balance in excess of insured limits.

Property, Plant and Equipment

Property and equipment are stated at cost. Major additions and improvements are capitalized in the month following the month in which the assets or improvement are deemed to be placed in service. Maintenance and repairs are expensed as incurred. Upon disposition, the net book value is eliminated from the accounts, with the resultant gain or loss reflected in operations. Depreciation expense is computed on a straight-line basis over the estimate useful lives of the assets as follows:

Building and leasehold improvements			10-25 years
Machinery and equipment			5 years
Furniture and fixtures			3-7 years

The Company periodically assesses the recoverability of property, plant and equipment and evaluates such assets for impairment whenever events or changes in circumstances indicate that the net carrying amount of an asset may not be recoverable. Asset impairment is determined to exist if estimated future cash flows, undiscounted and without interest charges, are less than the net carrying amount.

Impairment of Long-Lived Assets

The Company follows the provisions of ASC 360 for its long-lived assets. The Company’s long-lived assets, which include test equipment and purchased intellectual property rights, are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable.

F-8

TIGER OIL AND ENERGY, INC.

Notes to Consolidated Financial Statements

December 31, 2016 and 2015

NOTE 1 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

Impairment of Long-Lived Assets (Continued)

The Company assesses the recoverability of its long-lived assets by comparing the projected undiscounted net cash flows associated with the related long-lived asset or group of long-lived assets over their remaining estimated useful lives against their respective carrying amounts. Impairment, if any, is based on the excess of the carrying amount over the fair value of those assets. Fair value is generally determined using the asset’s expected future discounted cash flows or market value, if readily determinable. If long-lived assets are determined to be recoverable, but the newly determined remaining estimated useful lives are shorter than originally estimated, the net book values of the long-lived assets are depreciated over the newly determined remaining estimated useful lives.

The Company recognized impairment expense totaling $-0- and $404,837 for the years ended December 31, 2016 and 2015, respectively.

Fair Value of Financial Instruments

The fair value of a financial instrument is the amount that could be received upon the sale of an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Financial assets are marked to bid prices and financial liabilities are marked to offer prices. Fair value measurements do not include transaction costs. A fair value hierarchy is used to prioritize the quality and reliability of the information used to determine fair values. Categorization within the fair value hierarchy is based on the lowest level of input that is significant to the fair value measurement. The fair value hierarchy is defined into the following three categories:

Level 1: Quoted market prices in active markets for identical assets or liabilities

Level 2: Observable market-based inputs or inputs that are corroborated by market data

Level 3: Unobservable inputs that are not corroborated by market data

Stock-based Compensation

The Company adopted ASC 718 effective January 1, 2006 using the modified prospective method. Under this transition method, stock compensation expense includes compensation expense for all stock-based compensation awards granted on or after January 1, 2006, based on the grant-date fair value estimated in accordance with the provisions of ASC 718.

Provision for Taxes

The Company applies ASC 740, which requires the asset and liability method of accounting for income taxes. This method requires that the current or deferred tax consequences of all events recognized in the financial statements be measured by applying the provisions of enacted tax laws to determine the amount of taxes payable or refundable currently or in future years. Deferred tax assets are reviewed for recoverability and the Company records a valuation allowance to reduce its deferred tax assets when it is more likely than not that all or some portion of the deferred tax assets will not be recovered.

The Company adopted ASC 740, at the beginning of fiscal year 2008. This interpretation requires recognition and measurement of uncertain tax positions using a “more-likely-than-not” approach, requiring the recognition and measurement of uncertain tax positions. The adoption of ASC 740 had no material impact on the Company’s financial statements.

F-9

TIGER OIL AND ENERGY, INC.

Notes to Consolidated Financial Statements

December 31, 2016 and 2015

NOTE 1 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

Basic and Diluted Loss per Share

Basic and diluted loss per share is calculated by dividing the Company’s net loss applicable to common shareholders by the weighted average number of common shares during the period. Diluted earnings per share is calculated by dividing the Company’s net income available to common shareholders by the diluted weighted average number of shares outstanding during the year. The diluted weighted average number of shares outstanding is the basic weighted number of shares adjusted for any potentially dilutive debt or equity. The Company had 1,200,000 potential dilutive shares as of December 31, 2016 that were excluded as their effect was anti-dilutive.

Reporting Segments

ASC 280 establishes standards for the way that public enterprises report information about operating segments in annual financial statements and requires reporting of selected information about operating segments in interim financial statements regarding products and services, geographic areas and major customers. ASC 280 defines operating segments as components of an enterprise about which separate financial information is available that is evaluated regularly by the chief operating decision maker in deciding how to allocate resources and in assessing performances. Currently, ASC 280 has no effect on the Company’s consolidated financial statements as substantially all of the Company’s operations are conducted in one industry segment.

Oil and Gas Properties

The Company uses the full cost method of accounting for oil and natural gas properties. Under this method, all acquisition, exploration and development costs, including certain payroll, asset retirement costs, other internal costs, and interest incurred for the purpose of finding oil and natural gas reserves, are capitalized. Internal costs that are capitalized are directly attributable to acquisition, exploration and development activities and do not include costs related to production, general corporate overhead or similar activities. Costs associated with production and general corporate activities are expensed in the period incurred. Proceeds from the sale of oil and natural gas properties are applied to reduce the capitalized costs of oil and natural gas properties unless the sale would significantly alter the relationship between capitalized costs and proved reserves, in which case a gain or loss is recognized.

Capitalized costs associated with impaired properties and capitalized costs related to properties having proved reserves, plus the estimated future development costs, and asset retirement costs under Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic 410 “Asset Retirement and Environmental Obligations” (FASB ASC 410), are amortized using the unit-of-production method based on proved reserves. Capitalized costs of oil and natural gas properties, net of accumulated amortization and deferred income taxes, are limited to the total of estimated future net cash flows from proved oil and natural gas reserves, discounted at ten percent, plus the cost of unevaluated properties. Under certain specific conditions, companies could elect to use subsequent prices for determining the estimated future net cash flows. The use of subsequent pricing is no longer allowed. There are many factors, including global events that may influence the production, processing, marketing and price of oil and natural gas. A reduction in the valuation of oil and natural gas properties resulting from declining prices or production could adversely impact depletion rates and capitalized cost limitations. Capitalized costs associated with properties that have not been evaluated through drilling or seismic analysis, including exploration wells in progress at December 31, 2016, are excluded from the unit-of-production amortization. Exclusions are adjusted annually based on drilling results and interpretative analysis.

F-10

TIGER OIL AND ENERGY, INC.

Notes to Consolidated Financial Statements

December 31, 2016 and 2015

NOTE 1 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

Oil and Gas Properties (Continued)

Sales of oil and natural gas properties are accounted for as adjustments to the net full cost pool with no gain or loss recognized, unless the adjustment would significantly alter the relationship between capitalized costs and proved reserves. If it is determined that the relationship is significantly altered, the corresponding gain or loss will be recognized in the statements of operations.

Costs of oil and gas properties are depleted using the unit-of-production method. For the years ended December 31, 2016 and 2015, the Company recognized $-0- of depletion expense related to oil and gas production during the period.

Ceiling Test

In applying the full cost method, the Company performs an impairment test (ceiling test) at each reporting date, whereby the carrying value of property and equipment is compared to the value of its proved reserves discounted at a ten percent interest rate of future net revenues, based on current economic and operating conditions, plus the cost of properties not being amortized, plus the lower of cost or fair market value of unproved properties included in costs being amortized, less the income tax effects related to book and tax basis differences of the properties. During the years ended December 31, 2016 and 2015, the Company had recorded $-0- and $404,837, respectively, of impairment expense in connection with the full cost ceiling test calculation.

Asset Retirement Obligation

The Company follows ASC 410, Asset Retirement and Environmental Obligations which requires entities to record the fair value of a liability for asset retirement obligations (“ARO”) and recorded a corresponding increase in the carrying amount of the related long-lived asset. The asset retirement obligation primarily relates to the abandonment of oil and gas properties. The present value of the estimated asset retirement cost is capitalized as part of the carrying amount of oil and gas properties and is depleted over the useful life of the asset. The settlement date fair value is discounted at our credit adjusted risk-free rate in determining the abandonment liability. The abandonment liability is accreted with the passage of time to its expected settlement fair value. Revisions to such estimates are recorded as adjustments to ARO are charged to operations in the period in which they become known. At the time the abandonment cost is incurred, the Company is required to recognize a gain or loss if the actual costs do not equal the estimated costs included in ARO.

The ARO is based upon numerous estimates and assumptions, including future abandonment costs, future recoverable quantities of oil and gas, future inflation rates, and the credit adjusted risk free interest rate.

Recent Accounting Pronouncements

Management has considered all recent accounting pronouncements issued since the last audit of its consolidated financial statements. The Company’s management believes that these recent pronouncements will not have a material effect on the Company’s consolidated financial statements.

F-11

TIGER OIL AND ENERGY, INC.

Notes to Consolidated Financial Statements

December 31, 2016 and 2015

NOTE 2 - GOING CONCERN

The Company's financial statements are prepared using generally accepted accounting principles in the United States of America applicable to a going concern which contemplates the realization of assets and liquidation of liabilities in the normal course of business. The Company has not yet established an ongoing source of revenues sufficient to cover its operating costs and allow it to continue as a going concern. The ability of the Company to continue as a going concern is dependent on the Company obtaining adequate capital to fund operating losses until it becomes profitable. If the Company is unable to obtain adequate capital, it could be forced to cease operations.

In order to continue as a going concern, the Company will need, among other things, additional capital resources. Management's plan is to obtain such resources for the Company by obtaining capital from management and significant shareholders sufficient to meet its minimal operating expenses and seeking equity and/or debt financing. However management cannot provide any assurances that the Company will be successful in accomplishing any of its plans.

The ability of the Company to continue as a going concern is dependent upon its ability to successfully accomplish the plans described in the preceding paragraph and eventually secure other sources of financing and attain profitable operations. The accompanying financial statements do not include any adjustments that might be necessary if the Company is unable to continue as a going concern.

NOTE 3 - OIL AND GAS PROPERTIES

On April 3, 2014, the Company signed an election to participate in the first of three wells with Toto Energy, LLC in Cowley County, Kansas. The Company has a 30 percent working interest and a 24.45 percent net royalty interest in the well. As of December 31, 2016, the Company has capitalized $213,000 of cash payments made to commence operations development of the well.

On May 10, 2014, the Company signed an election to participate in the second of three wells with Toto Energy, LLC in Cowley County, Kansas. The Company has a 30 percent working interest and a 24.45 percent net royalty interest in the well. As of December 31, 2016, the Company has capitalized $189,000 of cash payments made to commence operations development of the well.

On July 23, 2016, the Company received $58,684 from the operator of two of its oil and gas leases. The payment received represented a partial refund of the Company’s previous $404,837 in payments made to the operator pursuant to the terms of an Authorization for Expenditures (“AFE”) Agreement. The Company’s original payments under the AFE were capitalized to oil and gas properties in 2014. All capitalized costs pursuant to the AFE were fully impaired during the year ended December 31, 2015. As the capitalized costs had been previously impaired, the $58,684 was recorded as a gain on property settlement for the period ended December 31, 2016.

Oil and gas properties are stated at cost. As of December 31, 2016, and December 31, 2015, oil and gas properties, net consisted of the following:

	December 31, 2016			December 31, 2015
Unproved properties	$	470,377		$	470,377
Impairment of oil and gas leases		(470,377	)		(470,377	)
Oil and gas properties, net	$	—		$	—

F-12

TIGER OIL AND ENERGY, INC.

Notes to Consolidated Financial Statements

December 31, 2016 and 2015

NOTE 4 - CONVERTIBLE NOTES PAYABLE

On January 3, 2014, the Company received $600,000 in connection with a convertible note financing commitment, the terms of which call for the Company to receive three tranches of $200,000 each on a callable convertible note wherein the Company borrows the sum at five percent interest for one year and the investor can elect to continue to receive the interest on the note or have the Company issue the investor shares of common stock of the Company at $0.50 per share to retire the debt. The notes came due on December 12, 2014, and as of December 31, 2016 the notes were in default. At December 31, 2016 accrued interest on the notes totaled $89,616.

The Company analyzed the convertible debts under ASC 470-20 and determined that a beneficial conversion feature existed at execution. The intrinsic value of the beneficial conversion feature was determined to be $400,000 and was recorded as additional paid-in capital with an offset to debt discounts. During the years ended December 31, 2016 and 2015, $-0- and $3,288 of the debt discount was amortized to interest expense, respectively, leaving an ending debt discount balance of $-0- at December 31, 2016 and 2015.

NOTE 5 - NOTES PAYABLE

On May 6, 2015 the Company borrowed $5,000 from an unrelated third-party entity. Pursuant to the terms of the note, the principal accrued interest at a rate of five percent per annum, was unsecured, and came due on May 6, 2016. During the 2016 calendar year, the Company paid the note in full, inclusive of $305 in accrued interest.

NOTE 6 - NOTES PAYABLE - RELATED PARTY

On June 11, 2015 the Company borrowed $5,000 from a related-party entity. Pursuant to the terms of the note, the principal accrues interest at a rate of five percent per annum, is unsecured, and is due in full on June 11, 2016. Subsequent to the initial borrowing the Company borrowed an additional $57,500 from the same lender under the same terms. On July 25, 2016 the Company paid $40,000 against the outstanding principal of the notes. Accrued interest totaling $1,340 was forgiven at the time of payment, and recorded as additional paid-in capital. At December 31, 2016 the total outstanding principal balance due to the lender was $22,500, and aggregate accrued interest on the notes totaled $465.

On May 6, 2015 the Company borrowed $5,000 from an unrelated third-party entity. Pursuant to the terms of the note, the principal accrues interest at a rate of five percent per annum, is unsecured, and is due in full on May 6, 2016. On July 25, 2015 the note, inclusive of all unpaid principal and interest, was transferred to and assumed by a related party. On July 25, 2016 the Company repaid the full $5,000 principal balance due under the terms of the note. Accrued interest on the note totaling $305 was forgiven at the time of payment, and recorded as additional paid-in capital. As of December 31, 2016 the note principal and interest have been satisfied in full.

On March 7, 2016 the Company borrowed $10,000 from a related-party. Pursuant to the terms of the note the principal accrues interest at a rate of five percent per annum, is unsecured, and is due in full on May 6, 2017. On May 2, 2016 the Company borrowed an additional $4,000 under the same terms. On October 4, 2016 the Company borrowed an additional $25,000 under the same terms. At December 31, 2016 the principal balances of the notes totaled $39,000 and accrued interest on the notes totaled $848.

F-13

TIGER OIL AND ENERGY, INC.

Notes to Consolidated Financial Statements

December 31, 2016 and 2015

NOTE 7 - ASSET RETIREMENT OBLIGATIONS

The total future asset retirement obligation is estimated by management based on the Company’s net working interests in all wells and facilities, estimated costs to reclaim and abandon wells and facilities and the estimated timing of the costs to be incurred in future periods. At December 31, 2016 and 2015, the Company estimated the undiscounted cash flows related to asset retirement obligation to total approximately $105,000. The actual costs to settle the obligation are expected to occur in approximately 25 years. Through December 31, 2016, the Company established an asset retirement obligation of $9,860 for the wells acquired by the Company, which was capitalized to the value of the oil and gas properties. The fair value of the liability at December 31, 2016 and 2015 is estimated to be $12,323 and $11,534, respectively, using a risk free rate of 9.31 percent and inflation rates between 3.87 and 4.81 percent. Total accretion expense on the asset retirement obligation was $789 and $715 for the years ended December 31, 2016 and 2015, respectively.

Changes to the asset retirement obligation for the years ended December 31, 2016 and 2015 were as follows:

	December 31, 2016		December 31, 2015

Balance, beginning of period	$	11,534	$	10,819
Liabilities incurred		—		—
Accretion expense		789		715
Balance, end of period	$	12,323	$	11,534

NOTE 8 - STOCKHOLDERS’ DEFICIT

The Company has 1,000,000 preferred shares authorized at a par value of $0.001 and 74,000,000 common shares authorized at par value of $0.001. As of December 31, 2016, the Company has 42,013 shares of preferred stock and 42,728,159 shares of common stock issued and outstanding.

NOTE 9 - RELATED-PARTY TRANSACTIONS

At December 31, 2016 and 2015 the Company was owed its directors an aggregate of $33,000 and $16,000, respectively, in accrued director fees.

F-14

TIGER OIL AND ENERGY, INC.

Notes to Consolidated Financial Statements

December 31, 2016 and 2015

NOTE 10 - INCOME TAXES

No provision has been made in the financial statements for income taxes because the Company has accumulated losses from operations since inception. Any deferred tax benefit arising from the operating loss carried forward is offset entirely by a valuation allowance since it is currently not likely that the Company will be significantly profitable in the near future to take advantage of the losses. The provision for income taxes consists of the following:

	For the Years Ended
	December 31,
	2016			2015
Current taxes	$	(29,550	)	$	(173,192	)
Impairment of oil and gas properties		—			137,645
Valuation allowance		29,550			35,547
Total provision for income taxes	$	—		$	—

The income tax provision differs from the amount of income tax determined by applying the U.S. federal and state income tax rates of 34% to pretax income from continuing operations for the years ended December 31, 2016 and 2015 due to the following:

	December 31,
	2016			2015
Loss carry forwards (expire through 2035)	$	1,636,324		$	1,568,832

Total gross deferred tax asset		698,751			718,676
Valuation allowance		(698,751	)		(718,676	)
Net deferred taxes	$	—		$	—

At December 31, 2016, the Company had net operating loss carry forwards of approximately $1,776,611 that may be offset against future taxable income through 2034. The Company adopted the provisions of ASC 740 at the beginning of fiscal year 2008. As a result of this adoption, the Company has not made any adjustments to deferred tax assets or liabilities. The Company did not identify any material uncertain tax positions on returns that have been filed or that will be filed. The Company has not had operations resulting in net income and is carrying a large Net Operating Loss as disclosed above. Since it is not thought that this Net Operating Loss will ever produce a tax benefit, even if examined by taxing authorities and disallowed entirely, there would be no effect on the financial statements.

NOTE 11 - COMMITMENTS AND CONTINGENCIES

During the year ended December 31, 2015 the Company became party to a legal action brought about by an unrelated third-party individual, wherein the plaintiff alleges the Company “participated and/or conspired in a scheme to disseminate spam emails” which were misleading in order to encourage individuals to purchase shares of the Company’s common stock at an artificial and/or inflated stock price.

On October 10, 2016, the Company reached a settlement agreement whereby the Company agreed to pay $11,000 in exchange for a general release of all claims against the Company. As of December 31, 2016, the case is considered fully resolved and closed.

F-15

TIGER OIL AND ENERGY, INC.

Notes to Consolidated Financial Statements

December 31, 2016 and 2015

NOTE 12 - SUBSEQUENT EVENTS

Subsequent to December 31, 2016, the Company cancelled 5,623,097 shares of common stock.

In accordance with ASC 855-10, Company management reviewed all material events through the date of this report and there are no additional material subsequent events to report.

F-16

TIGER OIL AND ENERGY, INC.

Notes to Consolidated Financial Statements

December 31, 2016 and 2015

SUPPLEMENTAL INFORMATION TO

FINANCIAL STATEMENTS (Unaudited)

Oil and Gas Producing Activities

In January 2010, the Financial Accounting Standards Board (FASB) issued FASB Accounting Standards Update (ASU) No. 2010-03, "Oil and Gas Reserve Estimations and Disclosures" (ASU No. 2010-03). This update aligns the current oil and gas reserve estimation and disclosure requirements of the Extractive Industries - Oil and Gas topic of the FASB Accounting Standards Codification (ASC Topic 932) with the changes required by the final rule of the Securities and Exchange Commission (the “SEC”), "Modernization of Oil and Gas Reporting." ASU No. 2010-03 must be applied prospectively as a change in accounting principle that is inseparable from a change in accounting estimate and is effective for entities with annual reporting periods ending on or after December 31, 2009.

Oil and Gas Reserves Users of this information should be aware that the process of estimating quantities of "proved," "proved developed," "proved undeveloped" and "probable" crude oil, natural gas liquids and natural gas reserves is complex, requiring significant subjective decisions in the evaluation of all available geological, engineering and economic data for each reservoir. The data for a given reservoir may also change substantially over time as a result of numerous factors including, but not limited to, additional development activity, evolving production history and continual reassessment of the viability of production under varying economic conditions. Consequently, material revisions (upward or downward) to existing reserve estimates may occur from time to time. Although reasonable effort is made to ensure that reserve estimates reported represent the most accurate assessments possible, the significance of the subjective decisions required and variances in available data for various reservoirs make these estimates generally less precise than other estimates presented in connection with financial statement disclosures. See ITEM 1A. Risk Factors.

Proved reserves represent estimated quantities of crude oil, natural gas liquids and natural gas that geoscience and engineering data can estimate, with reasonable certainty, to be economically producible from a given day forward from known reservoirs under economic conditions, operating methods and government regulation before the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation.

Proved developed reserves are proved reserves expected to be recovered under operating methods being utilized at the time the estimates were made, through wells and equipment in place or if the cost of any required equipment is relatively minor compared to the cost of a new well.

Proved undeveloped reserves are reserves that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required. Reserves on undrilled acreage are limited to those directly offsetting development spacing areas that are reasonably certain of production when drilled, unless evidence using reliable technology exists that establishes reasonable certainty of economic producibility at greater distances. Undrilled locations can be classified as having undeveloped reserves only if a development plan has been adopted indicating that they are scheduled to be drilled within five years, unless the specific circumstances justify a longer time. Estimates for proved undeveloped reserves are not attributed to any acreage for which an application of fluid injection or other improved recovery technique is contemplated, unless such techniques have been proved effective by actual projects in the same reservoir or an analogous reservoir, or by other evidence using reliable technology establishing reasonable certainty.

F-17

TIGER OIL AND ENERGY, INC.

Notes to Consolidated Financial Statements

December 31, 2016 and 2015

SUPPLEMENTAL INFORMATION TO

FINANCIAL STATEMENTS (Unaudited)

Oil and Gas Producing Activities (Continued)

Probable undeveloped reserves are those additional reserves that are less certain to be recovered than proved reserves but which, together with proved reserves, are as likely as not to be recovered. Probable reserves may be assigned to areas of a reservoir adjacent to proved reserves where data control or interpretations of available data are less certain, even if the interpreted reservoir continuity of structure or productivity does not meet the reasonable certainty criterion. Probable reserves may be assigned to areas that are structurally higher than the proved area if these areas are in communication with the proved reservoir.

No major acquisition or sale of oil and gas properties or other favorable or adverse event subsequent to December 31, 2016 is believed to have caused a material change in the estimates of proved developed or proved undeveloped or probable undeveloped reserves as of that date.

NET PROVED RESERVE SUMMARY

The following table sets forth the Company's net proved reserves, including proved developed and proved undeveloped reserves, at December 31, 2016 and 2015, as pursuant to reserve reports prepared by the Company’s independent, certified petroleum engineer.

	December 31, 2016	December 31, 2015

Net Proved Developed Reserves:
Crude oil (Bbls)	—	—
Natural gas (Mcf)	—	—
Oil equivalents (Boa)	—	—

Net Proved Undeveloped Reserves:
Crude oil (Bbls)	—	—
Natural gas (Mcf)	—	—
Oil equivalents (Boe)	—	—

Net Proved Developed and Undeveloped Reserves:
Crude oil (Bbls)	—	—
Natural gas (Mcf)	—	—
Oil equivalents (Boe)	—	—

F-18

TIGER OIL AND ENERGY, INC.

Notes to Consolidated Financial Statements

December 31, 2016 and 2015

SUPPLEMENTAL INFORMATION TO

FINANCIAL STATEMENTS (Unaudited)

Capitalized Costs Relating to Oil and Gas Producing Activities The following table sets forth the capitalized costs relating to the Company’s crude oil and natural gas producing activities at December 31, 2016 and 2015:

	At December 31, 2016			At December 31, 2015

Proved leasehold costs	$	—		$	—
Costs of wells and development		910,855			910,855
Capitalized asset retirement costs		9,860			9,860
Total cost of oil and gas properties		920,715			920,715
Accumulated depreciation, depletion, and impairment		(920,715	)		(920,715	)
Net Capitalized Costs	$	—		$	—

Costs Incurred in Oil and Gas Property Acquisition, Exploration and Development Activities The following table sets forth the costs incurred in the Company’s oil and gas property acquisition, exploration and development activities for the ended December 31, 2016 and 2015:

		For the Year Ended December 31, 2016		For the Year Ended December 31, 2015

Acquisition of properties:
Proved	$	—	$	—
Exploration costs		—		—
Development costs		—		—
Net Capitalized Costs	$	—	$	—

Results of Operations for Oil and Gas Producing Activities The following table sets forth the results of operations for oil and gas producing activities for the year ended December 31, 2016 and 2015:

	For the Year Ended December 31, 2016			For the Year Ended December 31, 2015

Crude oil and gas revenues	$	—		$	15,008
Production costs		(4,079	)		(679	)
Depreciation, depletion and accretion		(789	)		(715	)
Results of operations for producing activities, excluding corporate overhead	$	(4,868	)	$	13,614

F-19

TIGER OIL AND ENERGY, INC.

Notes to Consolidated Financial Statements

December 31, 2016 and 2015

SUPPLEMENTAL INFORMATION TO

FINANCIAL STATEMENTS (Unaudited)

Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves The following information has been developed utilizing procedures prescribed by ASC Topic 932 and is based on crude oil and natural gas reserves and production volumes estimated by the Company’s independent petroleum consultants. The estimates were based on a $43.92/BO crude oil price. The following information may be useful for certain comparison purposes, but should not be solely relied upon in evaluating the Company or its performance. Further, information contained in the following table should not be considered as representative of realistic assessments of future cash flows, nor should the Standardized Measure of Discounted Future Net Cash Flows be viewed as representative of the current value of the Company.

The future cash flows presented below are based on sales prices, cost rates and statutory income tax rates in existence as of the date of the projections. It is expected that material revisions to some estimates of crude oil and natural gas reserves may occur in the future, development and production of the reserves may occur in periods other than those assumed, and actual prices realized and costs incurred may vary significantly from those used.

Future production and development costs were computed by estimating those expenditures expected to occur in developing and producing the proved oil and natural gas reserves at the end of the year, based on year-end costs. Actual future cash inflows may vary considerably, and the standardized measure does not necessarily represent the fair value of the Company’s oil and natural gas reserves.

Management does not rely upon the following information in making investment and operating decisions. Such decisions are based upon a wide range of factors, including estimates of probable and possible reserves as well as proved reserves, and varying price and cost assumptions considered more representative of a range of possible economic conditions that may be anticipated.

The following table sets forth the standardized measure of discounted future net cash flows from projected production of the Company’s oil and gas reserves as of December 31, 2016 and 2015:

		December 31, 2016		December 31, 2015

Future cash inflows	$	—	$	—
Future production and development costs		—		—
Future income tax and insurance expense		—		—
Future net cash inflows		—		—
10% annual discount for estimated timing of cash flows		—		—
Standardized measure of discounted future net cash flows	$	—	$	—

F-20

TIGER OIL AND ENERGY, INC.

Notes to Consolidated Financial Statements

December 31, 2016 and 2015

SUPPLEMENTAL INFORMATION TO

FINANCIAL STATEMENTS (Unaudited)

Changes in Standardized Measure of Discounted Future Net Cash Flows The following table sets forth the changes in the standardized measure of discounted future net cash flows for the year ended December 31, 2016 and 2015:

		December 31, 2016		December 31, 2015

Beginning of period	$	—	$	—
Revenues less production and other costs		—		—
Changes in price, net of production costs		—		—
Development costs incurred		—		—
Net changes in future development costs		—		—
Purchases of reserves in place		—		—
Accretion of discount		—		—
Net change in income taxes		—		—
Timing differences and other		—		—
End of period	$	—	$	—

F-21

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~~Exhibit 31.1~~

CERTIFICATION PURSUANT TO SECTION 302
OF THE SARBANES-OXLEY ACT OF 2002

I, Kenneth B Liebscher certify that:

1. I have reviewed this annual report of Tiger Oil and Energy, Inc..

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

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

4. The Registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(3)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f) for the Registrant and have:

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

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

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

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

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

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

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

Date: April 14, 2017

/s/ Kenneth B Liebscher

Kenneth B Liebscher CEO

EX-31.2 5 exhibit31-2.htm EXHIBIT-31.2
Exhibit 31.2

CERTIFICATION PURSUANT TO SECTION 302
OF THE SARBANES-OXLEY ACT OF 2002

I, Howard Bouch, certify that:

1. I have reviewed this annual report of Tiger Oil and Energy, Inc

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

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

4. The Registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(3)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f) for the Registrant and have:

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

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

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

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

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

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

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

Date: April 14, 2017

/s/ Howard Bouch

Howard Bouch, CFO

EX-32.1 6 exhibit32-1.htm EXHIBIT-32.1
Exhibit 32.1

CERTIFICATION PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002
(18 U.S.C. SECTION 1350)

In connection with the Annual Report of Tiger Oil and Energy, In., a Nevada corporation (the “Company”), on Form 10-K for the year ending December 31, 2015, as filed with the Securities and Exchange Commission (the “Report”), I, Kenneth B Liebscher, CEO of the Company, certify, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (18 U.S.C. Section 1350), that to my knowledge:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and result of operations of the Company.

Date: April 14, 2017

/s/ Kenneth B Liebscher

Kenneth B Liebscher CEO

EX-32.2 7 exhibit32-2.htm EXHIBIT-32.2
Exhibit 32.2

CERTIFICATION PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002
(18 U.S.C. SECTION 1350)

In connection with the Annual Report of UTEC, Inc., a Nevada corporation (the “Company”), on Form 10-K for the year ending December 31, 2015, as filed with the Securities and Exchange Commission (the “Report”), I, Howard Bouch, CFO of the Company, certify, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (18 U.S.C. Section 1350), that to my knowledge:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and result of operations of the Company.

/s/ Howard Bouch

Howard Bouch CFO

Dated: April 14, 2017



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us-gaap:SubsequentEventMember 2017-01-01 2017-04-13 iso4217:USD xbrli:shares iso4217:USD xbrli:shares xbrli:pure utr:bbl utr:Mcf utr:Boe 213000 189000 404837 470377 470377 789 715 789 715 Tiger Oil & Energy, Inc. 0001386018 10-K 2016-12-31 false --12-31 No No Yes Smaller Reporting Company 2016 FY 35000 61500 22500 39000 16000 33000 33000 16000 470377 470377 66500 40000 5000 57500 10000 4000 25000 10819 11534 12323 12323 11534 40000 40000 5000 1645 1645 58684 58684 404837 404837 58684 58684 0 15247 472 15247 472 200 200 750712 821203 11534 12323 739178 808880 600000 600000 5200 82978 114380 42 42 42728 42728 4675176 4676821 -5453411 -5540322 -226077 -735465 -820731 42 42 42 42 42728 42728 42728 42728 4275176 4675176 4675176 4676821 -4457314 -4944023 -5453411 -5540322 -139368 15247 472 1000000 1000000 0.001 0.001 42013 42013 42013 42013 42013 42013 42013 42013 42013 42013 74000000 74000000 0.001 0.001 42728159 42728159 42728159 42728159 42728159 42728159 42728159 42728159 42728159 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The notes were in default It is unsecured, and is due in full. It is unsecured, and is due in full. It is unsecured, and is due in full. 0.05 0.05 0.05 0.05 The investor can elect to continue to receive the interest on the note or have the Company issue the investor shares of common stock of the Company at $0.50 per share to retire the debt.   2014-12-12 2016-05-06 2016-06-11 2017-05-06 89616 465 848 0 0 5000 1340 305 5000 105000 105000 P25Y 9860 0.0931 0.0931 0.0387 0.0481 0.0387 0.0481 0.34 1776611 At December 31, 2016, the Company had net operating loss carry forwards of approximately $1,776,611 that may be offset against future taxable income through 2034.   Unrelated third-party individual The Company The plaintiff alleges the Company participated and/or conspired in a scheme to disseminate spam emails which were misleading in order to encourage individuals to purchase shares of the Companys common stock at an artificial and/or inflated stock price. October 10, 2016 On October 10, 2016, the Company reached a settlement agreement whereby the Company agreed to pay $11,000 in exchange for a general release of all claims against the Company. As of December 31, 2016, the case is considered fully resolved and closed. NOTE 2 - GOING CONCERN   The Company's financial statements are prepared using generally accepted accounting principles in the United States of America applicable to a going concern which contemplates the realization of assets and liquidation of liabilities in the normal course of business. The Company has not yet established an ongoing source of revenues sufficient to cover its operating costs and allow it to continue as a going concern. The ability of the Company to continue as a going concern is dependent on the Company obtaining adequate capital to fund operating losses until it becomes profitable. If the Company is unable to obtain adequate capital, it could be forced to cease operations.   In order to continue as a going concern, the Company will need, among other things, additional capital resources. Management's plan is to obtain such resources for the Company by obtaining capital from management and significant shareholders sufficient to meet its minimal operating expenses and seeking equity and/or debt financing. However management cannot provide any assurances that the Company will be successful in accomplishing any of its plans.   The ability of the Company to continue as a going concern is dependent upon its ability to successfully accomplish the plans described in the preceding paragraph and eventually secure other sources of financing and attain profitable operations. The accompanying financial statements do not include any adjustments that might be necessary if the Company is unable to continue as a going concern. NOTE 3 - OIL AND GAS PROPERTIES   On April 3, 2014, the Company signed an election to participate in the first of three wells with Toto Energy, LLC in Cowley County, Kansas. The Company has a 30 percent working interest and a 24.45 percent net royalty interest in the well. As of December 31, 2016, the Company has capitalized $213,000 of cash payments made to commence operations development of the well.   On May 10, 2014, the Company signed an election to participate in the second of three wells with Toto Energy, LLC in Cowley County, Kansas. The Company has a 30 percent working interest and a 24.45 percent net royalty interest in the well. As of December 31, 2016, the Company has capitalized $189,000 of cash payments made to commence operations development of the well.   On July 23, 2016, the Company received $58,684 from the operator of two of its oil and gas leases. The payment received represented a partial refund of the Company’s previous $404,837 in payments made to the operator pursuant to the terms of an Authorization for Expenditures (“AFE”) Agreement. The Company’s original payments under the AFE were capitalized to oil and gas properties in 2014. All capitalized costs pursuant to the AFE were fully impaired during the year ended December 31, 2015. As the capitalized costs had been previously impaired, the $58,684 was recorded as a gain on property settlement for the period ended December 31, 2016.   Oil and gas properties are stated at cost. As of December 31, 2016, and December 31, 2015, oil and gas properties, net consisted of the following:   <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="vertical-align: bottom"> <td> </td><td style="padding-bottom: 1pt"> </td> <td colspan="3" style="text-align: center; border-bottom: Black 1pt solid">December 31, 2016</td><td style="padding-bottom: 1pt"> </td> <td colspan="3" style="text-align: center; border-bottom: Black 1pt solid">December 31, 2015</td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="width: 56%; text-align: left">Unproved properties</td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">470,377</td><td style="width: 1%; text-align: left"> </td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">470,377</td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-bottom: 1pt">Impairment of oil and gas leases</td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left"> </td><td style="border-bottom: Black 1pt solid; text-align: right">(470,377</td><td style="padding-bottom: 1pt; text-align: left">)</td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left"> </td><td style="border-bottom: Black 1pt solid; text-align: right">(470,377</td><td style="padding-bottom: 1pt; text-align: left">)</td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-bottom: 2.5pt">Oil and gas properties, net</td><td style="padding-bottom: 2.5pt"> </td> <td style="border-bottom: Black 2.5pt double; text-align: left">$</td><td style="border-bottom: Black 2.5pt double; text-align: right">—  </td><td style="padding-bottom: 2.5pt; text-align: left"> </td><td style="padding-bottom: 2.5pt"> </td> <td style="border-bottom: Black 2.5pt double; text-align: left">$</td><td style="border-bottom: Black 2.5pt double; text-align: right">—  </td><td style="padding-bottom: 2.5pt; text-align: left"> </td></tr></table> NOTE 4 - CONVERTIBLE NOTES PAYABLE   On January 3, 2014, the Company received $600,000 in connection with a convertible note financing commitment, the terms of which call for the Company to receive three tranches of $200,000 each on a callable convertible note wherein the Company borrows the sum at five percent interest for one year and the investor can elect to continue to receive the interest on the note or have the Company issue the investor shares of common stock of the Company at $0.50 per share to retire the debt. The notes came due on December 12, 2014, and as of December 31, 2016 the notes were in default. At December 31, 2016 accrued interest on the notes totaled $89,616.   The Company analyzed the convertible debts under ASC 470-20 and determined that a beneficial conversion feature existed at execution. The intrinsic value of the beneficial conversion feature was determined to be $400,000 and was recorded as additional paid-in capital with an offset to debt discounts. During the years ended December 31, 2016 and 2015, $-0- and $3,288 of the debt discount was amortized to interest expense, respectively, leaving an ending debt discount balance of $-0- at December 31, 2016 and 2015. NOTE 5 - NOTES PAYABLE   On May 6, 2015 the Company borrowed $5,000 from an unrelated third-party entity. Pursuant to the terms of the note, the principal accrued interest at a rate of five percent per annum, was unsecured, and came due on May 6, 2016. During the 2016 calendar year, the Company paid the note in full, inclusive of $305 in accrued interest. NOTE 6 - NOTES PAYABLE - RELATED PARTY   On June 11, 2015 the Company borrowed $5,000 from a related-party entity. Pursuant to the terms of the note, the principal accrues interest at a rate of five percent per annum, is unsecured, and is due in full on June 11, 2016. Subsequent to the initial borrowing the Company borrowed an additional $57,500 from the same lender under the same terms. On July 25, 2016 the Company paid $40,000 against the outstanding principal of the notes. Accrued interest totaling $1,340 was forgiven at the time of payment, and recorded as additional paid-in capital. At December 31, 2016 the total outstanding principal balance due to the lender was $22,500, and aggregate accrued interest on the notes totaled $465.   On May 6, 2015 the Company borrowed $5,000 from an unrelated third-party entity. Pursuant to the terms of the note, the principal accrues interest at a rate of five percent per annum, is unsecured, and is due in full on May 6, 2016. On July 25, 2015 the note, inclusive of all unpaid principal and interest, was transferred to and assumed by a related party. On July 25, 2016 the Company repaid the full $5,000 principal balance due under the terms of the note. Accrued interest on the note totaling $305 was forgiven at the time of payment, and recorded as additional paid-in capital. As of December 31, 2016 the note principal and interest have been satisfied in full.   On March 7, 2016 the Company borrowed $10,000 from a related-party. Pursuant to the terms of the note the principal accrues interest at a rate of five percent per annum, is unsecured, and is due in full on May 6, 2017. On May 2, 2016 the Company borrowed an additional $4,000 under the same terms. On October 4, 2016 the Company borrowed an additional $25,000 under the same terms. At December 31, 2016 the principal balances of the notes totaled $39,000 and accrued interest on the notes totaled $848. NOTE 7 - ASSET RETIREMENT OBLIGATIONS   The total future asset retirement obligation is estimated by management based on the Company’s net working interests in all wells and facilities, estimated costs to reclaim and abandon wells and facilities and the estimated timing of the costs to be incurred in future periods. At December 31, 2016 and 2015, the Company estimated the undiscounted cash flows related to asset retirement obligation to total approximately $105,000. The actual costs to settle the obligation are expected to occur in approximately 25 years. Through December 31, 2016, the Company established an asset retirement obligation of $9,860 for the wells acquired by the Company, which was capitalized to the value of the oil and gas properties. The fair value of the liability at December 31, 2016 and 2015 is estimated to be $12,323 and $11,534, respectively, using a risk free rate of 9.31 percent and inflation rates between 3.87 and 4.81 percent. Total accretion expense on the asset retirement obligation was $789 and $715 for the years ended December 31, 2016 and 2015, respectively.   Changes to the asset retirement obligation for the years ended December 31, 2016 and 2015 were as follows:   <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="vertical-align: bottom"> <td> </td><td style="padding-bottom: 1pt"> </td> <td colspan="3" style="text-align: center; border-bottom: Black 1pt solid">December 31, 2016</td><td style="padding-bottom: 1pt"> </td> <td colspan="3" style="text-align: center; border-bottom: Black 1pt solid">December 31, 2015</td></tr> <tr style="vertical-align: bottom"> <td> </td><td> </td> <td colspan="3"> </td><td> </td> <td colspan="3"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="width: 56%; padding-left: 5.4pt">Balance, beginning of period</td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">11,534</td><td style="width: 1%; text-align: left"> </td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">10,819</td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt">Liabilities incurred</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-bottom: 1pt; padding-left: 5.4pt">Accretion expense</td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left"> </td><td style="border-bottom: Black 1pt solid; text-align: right">789</td><td style="padding-bottom: 1pt; text-align: left"> </td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left"> </td><td style="border-bottom: Black 1pt solid; text-align: right">715</td><td style="padding-bottom: 1pt; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="padding-bottom: 2.5pt; padding-left: 5.4pt">Balance, end of period</td><td style="padding-bottom: 2.5pt"> </td> <td style="border-bottom: Black 2.5pt double; text-align: left">$</td><td style="border-bottom: Black 2.5pt double; text-align: right">12,323</td><td style="padding-bottom: 2.5pt; text-align: left"> </td><td style="padding-bottom: 2.5pt"> </td> <td style="border-bottom: Black 2.5pt double; text-align: left">$</td><td style="border-bottom: Black 2.5pt double; text-align: right">11,534</td><td style="padding-bottom: 2.5pt; text-align: left"> </td></tr></table> NOTE 8 - STOCKHOLDERS’ DEFICIT   The Company has 1,000,000 preferred shares authorized at a par value of $0.001 and 74,000,000 common shares authorized at par value of $0.001.  As of December 31, 2016, the Company has 42,013 shares of preferred stock and 42,728,159 shares of common stock issued and outstanding.  NOTE 9 - RELATED-PARTY TRANSACTIONS   At December 31, 2016 and 2015 the Company was owed its directors an aggregate of $33,000 and $16,000, respectively, in accrued director fees. NOTE 10 - INCOME TAXES   No provision has been made in the financial statements for income taxes because the Company has accumulated losses from operations since inception.  Any deferred tax benefit arising from the operating loss carried forward is offset entirely by a valuation allowance since it is currently not likely that the Company will be significantly profitable in the near future to take advantage of the losses.  The provision for income taxes consists of the following:   <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="vertical-align: bottom"> <td> </td><td> </td> <td colspan="7" style="text-align: center">For the Years Ended</td></tr> <tr style="vertical-align: bottom"> <td> </td><td style="padding-bottom: 1pt"> </td> <td colspan="7" style="text-align: center; border-bottom: Black 1pt solid">December 31,</td></tr> <tr style="vertical-align: bottom"> <td> </td><td style="padding-bottom: 1pt"> </td> <td colspan="3" style="text-align: center; border-bottom: Black 1pt solid">2016</td><td style="padding-bottom: 1pt"> </td> <td colspan="3" style="text-align: center; border-bottom: Black 1pt solid">2015</td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="width: 56%; text-align: left; padding-left: 5.4pt">Current taxes</td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">(29,550</td><td style="width: 1%; text-align: left">)</td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">(173,192</td><td style="width: 1%; text-align: left">)</td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt">Impairment of oil and gas properties</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">137,645</td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-bottom: 1pt; padding-left: 5.4pt">Valuation allowance</td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left"> </td><td style="border-bottom: Black 1pt solid; text-align: right">29,550</td><td style="padding-bottom: 1pt; text-align: left"> </td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left"> </td><td style="border-bottom: Black 1pt solid; text-align: right">35,547</td><td style="padding-bottom: 1pt; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-bottom: 1pt; padding-left: 5.4pt">Total provision for income taxes</td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left">$</td><td style="border-bottom: Black 1pt solid; text-align: right">—  </td><td style="padding-bottom: 1pt; text-align: left"> </td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left">$</td><td style="border-bottom: Black 1pt solid; text-align: right">—  </td><td style="padding-bottom: 1pt; text-align: left"> </td></tr> </table>   The income tax provision differs from the amount of income tax determined by applying the U.S. federal and state income tax rates of 34% to pretax income from continuing operations for the years ended December 31, 2016 and 2015 due to the following:   <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="vertical-align: bottom"> <td> </td><td style="padding-bottom: 1pt"> </td> <td colspan="7" style="text-align: center; border-bottom: Black 1pt solid">December 31,</td></tr> <tr style="vertical-align: bottom"> <td> </td><td style="padding-bottom: 1pt"> </td> <td colspan="3" style="text-align: center; border-bottom: Black 1pt solid">2016</td><td style="padding-bottom: 1pt"> </td> <td colspan="3" style="text-align: center; border-bottom: Black 1pt solid">2015</td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="width: 56%; text-align: left; padding-left: 5.4pt">Loss carry forwards (expire through 2035)</td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">1,636,324</td><td style="width: 1%; text-align: left"> </td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">1,568,832</td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="padding-left: 5.4pt"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt">Total gross deferred tax asset</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">698,751</td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">718,676</td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-bottom: 1pt; padding-left: 5.4pt">Valuation allowance</td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left"> </td><td style="border-bottom: Black 1pt solid; text-align: right">(698,751</td><td style="padding-bottom: 1pt; text-align: left">)</td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left"> </td><td style="border-bottom: Black 1pt solid; text-align: right">(718,676</td><td style="padding-bottom: 1pt; text-align: left">)</td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-bottom: 1pt; padding-left: 5.4pt">Net deferred taxes</td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left">$</td><td style="border-bottom: Black 1pt solid; text-align: right">—  </td><td style="padding-bottom: 1pt; text-align: left"> </td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left">$</td><td style="border-bottom: Black 1pt solid; text-align: right">—  </td><td style="padding-bottom: 1pt; text-align: left"> </td></tr> </table>   At December 31, 2016, the Company had net operating loss carry forwards of approximately $1,776,611 that may be offset against future taxable income through 2034.  The Company adopted the provisions of ASC 740 at the beginning of fiscal year 2008. As a result of this adoption, the Company has not made any adjustments to deferred tax assets or liabilities. The Company did not identify any material uncertain tax positions on returns that have been filed or that will be filed. The Company has not had operations resulting in net income and is carrying a large Net Operating Loss as disclosed above.  Since it is not thought that this Net Operating Loss will ever produce a tax benefit, even if examined by taxing authorities and disallowed entirely, there would be no effect on the financial statements. NOTE 11 - COMMITMENTS AND CONTINGENCIES   During the year ended December 31, 2015 the Company became party to a legal action brought about by an unrelated third-party individual, wherein the plaintiff alleges the Company “participated and/or conspired in a scheme to disseminate spam emails” which were misleading in order to encourage individuals to purchase shares of the Company’s common stock at an artificial and/or inflated stock price.   On October 10, 2016, the Company reached a settlement agreement whereby the Company agreed to pay $11,000 in exchange for a general release of all claims against the Company. As of December 31, 2016, the case is considered fully resolved and closed. NOTE 12 - SUBSEQUENT EVENTS   Subsequent to December 31, 2016, the Company cancelled 5,623,097 shares of common stock. In accordance with ASC 855-10, Company management reviewed all material events through the date of this report and there are no additional material subsequent events to report. SUPPLEMENTAL INFORMATION TO FINANCIAL STATEMENTS (Unaudited)   Oil and Gas Producing Activities   In January 2010, the Financial Accounting Standards Board (FASB) issued FASB Accounting Standards Update (ASU) No. 2010-03, "Oil and Gas Reserve Estimations and Disclosures" (ASU No. 2010-03). This update aligns the current oil and gas reserve estimation and disclosure requirements of the Extractive Industries - Oil and Gas topic of the FASB Accounting Standards Codification (ASC Topic 932) with the changes required by the final rule of the Securities and Exchange Commission (the “SEC”), "Modernization of Oil and Gas Reporting." ASU No. 2010-03 must be applied prospectively as a change in accounting principle that is inseparable from a change in accounting estimate and is effective for entities with annual reporting periods ending on or after December 31, 2009.   Oil and Gas Reserves  Users of this information should be aware that the process of estimating quantities of "proved," "proved developed," "proved undeveloped" and "probable" crude oil, natural gas liquids and natural gas reserves is complex, requiring significant subjective decisions in the evaluation of all available geological, engineering and economic data for each reservoir. The data for a given reservoir may also change substantially over time as a result of numerous factors including, but not limited to, additional development activity, evolving production history and continual reassessment of the viability of production under varying economic conditions. Consequently, material revisions (upward or downward) to existing reserve estimates may occur from time to time. Although reasonable effort is made to ensure that reserve estimates reported represent the most accurate assessments possible, the significance of the subjective decisions required and variances in available data for various reservoirs make these estimates generally less precise than other estimates presented in connection with financial statement disclosures. See ITEM 1A. Risk Factors.   Proved reserves represent estimated quantities of crude oil, natural gas liquids and natural gas that geoscience and engineering data can estimate, with reasonable certainty, to be economically producible from a given day forward from known reservoirs under economic conditions, operating methods and government regulation before the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation.   Proved developed reserves are proved reserves expected to be recovered under operating methods being utilized at the time the estimates were made, through wells and equipment in place or if the cost of any required equipment is relatively minor compared to the cost of a new well.   Proved undeveloped reserves are reserves that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required. Reserves on undrilled acreage are limited to those directly offsetting development spacing areas that are reasonably certain of production when drilled, unless evidence using reliable technology exists that establishes reasonable certainty of economic producibility at greater distances. Undrilled locations can be classified as having undeveloped reserves only if a development plan has been adopted indicating that they are scheduled to be drilled within five years, unless the specific circumstances justify a longer time. Estimates for proved undeveloped reserves are not attributed to any acreage for which an application of fluid injection or other improved recovery technique is contemplated, unless such techniques have been proved effective by actual projects in the same reservoir or an analogous reservoir, or by other evidence using reliable technology establishing reasonable certainty.   Probable undeveloped reserves are those additional reserves that are less certain to be recovered than proved reserves but which, together with proved reserves, are as likely as not to be recovered. Probable reserves may be assigned to areas of a reservoir adjacent to proved reserves where data control or interpretations of available data are less certain, even if the interpreted reservoir continuity of structure or productivity does not meet the reasonable certainty criterion. Probable reserves may be assigned to areas that are structurally higher than the proved area if these areas are in communication with the proved reservoir.   No major acquisition or sale of oil and gas properties or other favorable or adverse event subsequent to December 31, 2016 is believed to have caused a material change in the estimates of proved developed or proved undeveloped or probable undeveloped reserves as of that date.    NET PROVED RESERVE SUMMARY   The following table sets forth the Company's net proved reserves, including proved developed and proved undeveloped reserves, at December 31, 2016 and 2015, as pursuant to reserve reports prepared by the Company’s independent, certified petroleum engineer.    <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="text-align: center; background-color: White; vertical-align: bottom"> <td style="padding-bottom: 1pt; padding-left: 5.4pt"> </td><td style="font-weight: bold; padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; font-weight: bold"> </td><td style="border-bottom: Black 1pt solid; font-weight: bold">December 31, 2016</td><td style="padding-bottom: 1pt; font-weight: bold"> </td><td style="font-weight: bold; padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; font-weight: bold"> </td><td style="border-bottom: Black 1pt solid; font-weight: bold">December 31, 2015</td><td style="padding-bottom: 1pt; font-weight: bold"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="padding-left: 5.4pt"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt">Net Proved Developed Reserves:</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="width: 56%; text-align: left; padding-left: 5.4pt">   Crude oil (Bbls)</td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left"> </td><td style="width: 12%; text-align: right">—  </td><td style="width: 1%; text-align: left"> </td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left"> </td><td style="width: 12%; text-align: right">—  </td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt">   Natural gas (Mcf)</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt">   Oil equivalents (Boa)</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="padding-left: 5.4pt"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt">Net Proved Undeveloped Reserves:</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt">   Crude oil (Bbls)</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt">   Natural gas (Mcf)</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt">   Oil equivalents (Boe)</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="padding-left: 5.4pt"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt">Net Proved Developed and Undeveloped Reserves:</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt">   Crude oil (Bbls)</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt">   Natural gas (Mcf)</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt">   Oil equivalents (Boe)</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> </table>   Capitalized Costs Relating to Oil and Gas Producing Activities The following table sets forth the capitalized costs relating to the Company’s crude oil and natural gas producing activities at December 31, 2016 and 2015:   <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="vertical-align: bottom"> <td style="padding-bottom: 1pt"> </td><td style="font-weight: bold; padding-bottom: 1pt"> </td> <td colspan="3" style="font-weight: bold; text-align: center; border-bottom: Black 1pt solid">At December 31, 2016</td><td style="font-weight: bold; padding-bottom: 1pt"> </td> <td colspan="3" style="font-weight: bold; text-align: center; border-bottom: Black 1pt solid">At December 31, 2015</td></tr> <tr style="vertical-align: bottom"> <td> </td><td> </td> <td colspan="3"> </td><td> </td> <td colspan="3"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt">Proved leasehold costs</td><td> </td> <td style="text-align: left">$</td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left">$</td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="width: 56%; text-align: left; padding-left: 5.4pt">Costs of wells and development</td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left"> </td><td style="width: 12%; text-align: right">910,855</td><td style="width: 1%; text-align: left"> </td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left"> </td><td style="width: 12%; text-align: right">910,855</td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt">Capitalized asset retirement costs</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">9,860</td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">9,860</td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt">Total cost of oil and gas properties</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">920,715</td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">920,715</td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt; padding-bottom: 1pt">Accumulated depreciation, depletion, and impairment</td><td style="padding-bottom: 1pt"> </td> <td style="text-align: left; border-bottom: Black 1pt solid"> </td><td style="text-align: right; border-bottom: Black 1pt solid">(920,715</td><td style="text-align: left; padding-bottom: 1pt">)</td><td style="padding-bottom: 1pt"> </td> <td style="text-align: left; border-bottom: Black 1pt solid"> </td><td style="text-align: right; border-bottom: Black 1pt solid">(920,715</td><td style="text-align: left; padding-bottom: 1pt">)</td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt; padding-bottom: 2.5pt">Net Capitalized Costs</td><td style="padding-bottom: 2.5pt"> </td> <td style="text-align: left; border-bottom: Black 2.5pt double">$</td><td style="text-align: right; border-bottom: Black 2.5pt double">—  </td><td style="text-align: left; padding-bottom: 2.5pt"> </td><td style="padding-bottom: 2.5pt"> </td> <td style="text-align: left; border-bottom: Black 2.5pt double">$</td><td style="text-align: right; border-bottom: Black 2.5pt double">—  </td><td style="text-align: left; padding-bottom: 2.5pt"> </td></tr> </table>   Costs Incurred in Oil and Gas Property Acquisition, Exploration and Development Activities The following table sets forth the costs incurred in the Company’s oil and gas property acquisition, exploration and development activities for the ended December 31, 2016 and 2015:   <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="text-align: center; background-color: White; vertical-align: bottom"> <td style="padding-left: 5.4pt; padding-bottom: 1pt"> </td><td style="font-weight: bold; padding-bottom: 1pt"> </td> <td style="font-weight: bold; padding-bottom: 1pt"> </td><td style="font-weight: bold; border-bottom: Black 1pt solid">For the Year Ended December 31, 2016</td><td style="font-weight: bold; padding-bottom: 1pt"> </td><td style="font-weight: bold; padding-bottom: 1pt"> </td> <td style="font-weight: bold; padding-bottom: 1pt"> </td><td style="font-weight: bold; border-bottom: Black 1pt solid">For the Year Ended December 31, 2015</td><td style="font-weight: bold; padding-bottom: 1pt"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="padding-left: 5.4pt"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="padding-left: 5.4pt">Acquisition of properties:</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="width: 56%; padding-left: 5.4pt">   Proved</td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">—  </td><td style="width: 1%; text-align: left"> </td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">—  </td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt">   Exploration costs</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt; padding-bottom: 1pt">   Development costs</td><td style="padding-bottom: 1pt"> </td> <td style="text-align: left; border-bottom: Black 1pt solid"> </td><td style="text-align: right; border-bottom: Black 1pt solid">—  </td><td style="text-align: left; padding-bottom: 1pt"> </td><td style="padding-bottom: 1pt"> </td> <td style="text-align: left; border-bottom: Black 1pt solid"> </td><td style="text-align: right; border-bottom: Black 1pt solid">—  </td><td style="text-align: left; padding-bottom: 1pt"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt; padding-bottom: 2.5pt">Net Capitalized Costs</td><td style="padding-bottom: 2.5pt"> </td> <td style="text-align: left; border-bottom: Black 2.5pt double">$</td><td style="text-align: right; border-bottom: Black 2.5pt double">—  </td><td style="text-align: left; padding-bottom: 2.5pt"> </td><td style="padding-bottom: 2.5pt"> </td> <td style="text-align: left; border-bottom: Black 2.5pt double">$</td><td style="text-align: right; border-bottom: Black 2.5pt double">—  </td><td style="text-align: left; padding-bottom: 2.5pt"> </td></tr> </table>   Results of Operations for Oil and Gas Producing Activities The following table sets forth the results of operations for oil and gas producing activities for the year ended December 31, 2016 and 2015:   <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="vertical-align: bottom"> <td style="padding-bottom: 1pt"> </td><td style="font-weight: bold; padding-bottom: 1pt"> </td> <td colspan="3" style="font-weight: bold; text-align: center; border-bottom: Black 1pt solid">For the Year Ended December 31, 2016</td><td style="font-weight: bold; padding-bottom: 1pt"> </td> <td colspan="3" style="font-weight: bold; text-align: center; border-bottom: Black 1pt solid">For the Year Ended December 31, 2015</td></tr> <tr style="vertical-align: bottom"> <td> </td><td> </td> <td colspan="3"> </td><td> </td> <td colspan="3"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="width: 56%; text-align: left; padding-left: 5.4pt">Crude oil and gas revenues</td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">—  </td><td style="width: 1%; text-align: left"> </td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">15,008</td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt">Production costs</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">(4,079</td><td style="text-align: left">)</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">(679</td><td style="text-align: left">)</td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt; padding-bottom: 1pt">Depreciation, depletion and accretion</td><td style="padding-bottom: 1pt"> </td> <td style="text-align: left; border-bottom: Black 1pt solid"> </td><td style="text-align: right; border-bottom: Black 1pt solid">(789</td><td style="text-align: left; padding-bottom: 1pt">)</td><td style="padding-bottom: 1pt"> </td> <td style="text-align: left; border-bottom: Black 1pt solid"> </td><td style="text-align: right; border-bottom: Black 1pt solid">(715</td><td style="text-align: left; padding-bottom: 1pt">)</td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt; padding-bottom: 2.5pt">Results of operations for producing activities, excluding corporate overhead</td><td style="padding-bottom: 2.5pt"> </td> <td style="text-align: left; border-bottom: Black 2.5pt double">$</td><td style="text-align: right; border-bottom: Black 2.5pt double">(4,868</td><td style="text-align: left; padding-bottom: 2.5pt">)</td><td style="padding-bottom: 2.5pt"> </td> <td style="text-align: left; border-bottom: Black 2.5pt double">$</td><td style="text-align: right; border-bottom: Black 2.5pt double">13,614</td><td style="text-align: left; padding-bottom: 2.5pt"> </td></tr> </table>   Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves  The following information has been developed utilizing procedures prescribed by ASC Topic 932 and is based on crude oil and natural gas reserves and production volumes estimated by the Company’s independent petroleum consultants. The estimates were based on a $43.92/BO crude oil price. The following information may be useful for certain comparison purposes, but should not be solely relied upon in evaluating the Company or its performance. Further, information contained in the following table should not be considered as representative of realistic assessments of future cash flows, nor should the Standardized Measure of Discounted Future Net Cash Flows be viewed as representative of the current value of the Company.   The future cash flows presented below are based on sales prices, cost rates and statutory income tax rates in existence as of the date of the projections. It is expected that material revisions to some estimates of crude oil and natural gas reserves may occur in the future, development and production of the reserves may occur in periods other than those assumed, and actual prices realized and costs incurred may vary significantly from those used.   Future production and development costs were computed by estimating those expenditures expected to occur in developing and producing the proved oil and natural gas reserves at the end of the year, based on year-end costs. Actual future cash inflows may vary considerably, and the standardized measure does not necessarily represent the fair value of the Company’s oil and natural gas reserves.   Management does not rely upon the following information in making investment and operating decisions. Such decisions are based upon a wide range of factors, including estimates of probable and possible reserves as well as proved reserves, and varying price and cost assumptions considered more representative of a range of possible economic conditions that may be anticipated.   The following table sets forth the standardized measure of discounted future net cash flows from projected production of the Company’s oil and gas reserves as of December 31, 2016 and 2015:    <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="text-align: center; background-color: White; vertical-align: bottom"> <td style="text-indent: -8.1pt; padding-left: 8.1pt"> </td><td style="font-weight: bold"> </td> <td style="font-weight: bold"> </td><td style="font-weight: bold">December 31, 2016</td><td style="font-weight: bold"> </td><td style="font-weight: bold"> </td> <td style="font-weight: bold"> </td><td style="font-weight: bold">December 31, 2015</td><td style="font-weight: bold"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="padding-left: 5.4pt"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="width: 56%; text-align: left; padding-left: 5.4pt">Future cash inflows</td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">—  </td><td style="width: 1%; text-align: left"> </td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">—  </td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt">Future production and development costs</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt">Future income tax and insurance expense</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt">Future net cash inflows</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt; padding-bottom: 1pt">10% annual discount for estimated timing of cash flows</td><td style="padding-bottom: 1pt"> </td> <td style="text-align: left; border-bottom: Black 1pt solid"> </td><td style="text-align: right; border-bottom: Black 1pt solid">—  </td><td style="text-align: left; padding-bottom: 1pt"> </td><td style="padding-bottom: 1pt"> </td> <td style="text-align: left; border-bottom: Black 1pt solid"> </td><td style="text-align: right; border-bottom: Black 1pt solid">—  </td><td style="text-align: left; padding-bottom: 1pt"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt; padding-bottom: 2.5pt">Standardized measure of discounted future net cash flows</td><td style="padding-bottom: 2.5pt"> </td> <td style="text-align: left; border-bottom: Black 2.5pt double">$</td><td style="text-align: right; border-bottom: Black 2.5pt double">—  </td><td style="text-align: left; padding-bottom: 2.5pt"> </td><td style="padding-bottom: 2.5pt"> </td> <td style="text-align: left; border-bottom: Black 2.5pt double">$</td><td style="text-align: right; border-bottom: Black 2.5pt double">—  </td><td style="text-align: left; padding-bottom: 2.5pt"> </td></tr> </table>   Changes in Standardized Measure of Discounted Future Net Cash Flows  The following table sets forth the changes in the standardized measure of discounted future net cash flows for the year ended December 31, 2016 and 2015:   <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="text-align: center; background-color: White; vertical-align: bottom"> <td style="padding-left: 5.4pt; padding-bottom: 1pt"> </td><td style="font-weight: bold; padding-bottom: 1pt"> </td> <td style="font-weight: bold; padding-bottom: 1pt"> </td><td style="font-weight: bold; border-bottom: Black 1pt solid">December 31, 2016</td><td style="font-weight: bold; padding-bottom: 1pt"> </td><td style="font-weight: bold; padding-bottom: 1pt"> </td> <td style="font-weight: bold; padding-bottom: 1pt"> </td><td style="font-weight: bold; border-bottom: Black 1pt solid">December 31, 2015</td><td style="font-weight: bold; padding-bottom: 1pt"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: justify; padding-left: 5.4pt"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="width: 56%; text-align: justify; padding-left: 5.4pt">Beginning of period</td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">—  </td><td style="width: 1%; text-align: left"> </td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">—  </td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: justify; padding-left: 5.4pt">  Revenues less production and other costs</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: justify; padding-left: 5.4pt">  Changes in price, net of production costs</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: justify; padding-left: 5.4pt">  Development costs incurred</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: justify; padding-left: 5.4pt">  Net changes in future development costs</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: justify; padding-left: 5.4pt">  Purchases of reserves in place</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: justify; padding-left: 5.4pt">  Accretion of discount</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: justify; padding-left: 5.4pt">  Net change in income taxes</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: justify; padding-left: 5.4pt; padding-bottom: 1pt">  Timing differences and other</td><td style="padding-bottom: 1pt"> </td> <td style="text-align: left; border-bottom: Black 1pt solid"> </td><td style="text-align: right; border-bottom: Black 1pt solid">—  </td><td style="text-align: left; padding-bottom: 1pt"> </td><td style="padding-bottom: 1pt"> </td> <td style="text-align: left; border-bottom: Black 1pt solid"> </td><td style="text-align: right; border-bottom: Black 1pt solid">—  </td><td style="text-align: left; padding-bottom: 1pt"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: justify; padding-left: 5.4pt; padding-bottom: 2.5pt">End of period</td><td style="padding-bottom: 2.5pt"> </td> <td style="text-align: left; border-bottom: Black 2.5pt double">$</td><td style="text-align: right; border-bottom: Black 2.5pt double">—  </td><td style="text-align: left; padding-bottom: 2.5pt"> </td><td style="padding-bottom: 2.5pt"> </td> <td style="text-align: left; border-bottom: Black 2.5pt double">$</td><td style="text-align: right; border-bottom: Black 2.5pt double">—  </td><td style="text-align: left; padding-bottom: 2.5pt"> </td></tr></table> Business Activity   Tiger Oil and Energy, Inc., formerly UTeC, Inc., is a Nevada corporation organized on November 8, 1993 as a “For Profit” corporation for the purpose of engaging in any lawful activity.   On January 10, 2007, the Company purchased 100% of the shares of UTeC Corporation, Inc.   In 2007, the Company licensed technology covering the use of cold plasma oxidizer technology for the destruction of solid and liquid hazardous chemicals and biologicals.  During 2007 and 2008, the Company worked to validate the technology and prepare a business plan for its commercialization.   In April 2009, the Company divested its commercial explosives development, analysis, testing and manufacturing business to eliminate the need to inject new capital into the Company to support this business, and concentrate on raising the funds necessary to commercialize its hazardous waste destruction business.  At this time, the Company re-entered the development stage.   Prior to the divestiture, the Company’s business was to offer state of the art testing and analysis to clients worldwide.  The Company operated a chemical research and development laboratory near Riverton, Kansas, which specialized in commercial explosives development and analysis. The Company also operated a destructive test facility near Hallowell, Kansas, which specialized in determining the detonating characteristics of commercial explosives.   On October 1, 2009 the Company entered into an agreement to purchase 100% of the outstanding shares of C2R Energy Commodities, Inc., a Nevada corporation, in exchange for 4,050,000 shares of the Company’s restricted common stock.  The Company entered into this agreement due primarily to the fact that C2R owned certain intellectual property that the Company wished to acquire.   On October 29, 2010, the Company acquired all of the membership interest in Jett Rink Oil, LLC (“Jett Rink”) in exchange for 10,000,000 shares of the Company’s Common Stock.  Jett Rink is involved in the business relating to the exploration, development and production of oil and gas in the United States. At the closing of the Exchange Agreement, Jett Rink became a wholly-owned subsidiary of the Company and the Company acquired the business and operations of Jett Rink. Basis of Presentation   The accompanying audited consolidated financial statements and related notes include the activity of the Company and its two wholly-owned subsidiaries, C2R Energy Commodities, Inc. and Jett Rink Oil, LLC and have been prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”) and with the rules and regulations of the United States Securities and Exchange Commission (“SEC”) to Form 10-K. All inter-company balances and transactions have been eliminated. Reclassification   Certain amounts in the prior period financial statements have been reclassified to conform to the current period presentation.   These reclassifications had no effect on reported losses. Consolidation    The accompanying consolidated financial statements included all of the accounts of the Company and its wholly-owned subsidiaries, C2R, Inc., a Nevada Corporation, and Jett Rink Oil, LLC, a Kansas Limited Liability Company. All intercompany transactions have been eliminated. Accounting Method   The Company’s financial statements are prepared using the accrual method of accounting.  The Company has elected a December 31 year-end. Use of Estimates   The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period.  Actual results could differ from those estimates. Cash and Cash Equivalents   For purposes of the Statement of Cash Flows, the Company considers all highly liquid instruments purchased with a maturity of three months or less to be cash equivalents to the extent the funds are not being held for investment purposes.  The Company at times may maintain a cash balance in excess of insured limits. Property, Plant and Equipment   Property and equipment are stated at cost.  Major additions and improvements are capitalized in the month following the month in which the assets or improvement are deemed to be placed in service. Maintenance and repairs are expensed as incurred. Upon disposition, the net book value is eliminated from the accounts, with the resultant gain or loss reflected in operations. Depreciation expense is computed on a straight-line basis over the estimate useful lives of the assets as follows:   <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="width: 45%; text-align: justify; padding-left: 5.4pt">Building and leasehold improvements</td><td style="width: 10%"> </td> <td style="width: 1%; text-align: left"> </td><td style="width: 43%; text-align: right">10-25 years</td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: justify; padding-left: 5.4pt">Machinery and equipment</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">5 years</td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: justify; padding-left: 5.4pt">Furniture and fixtures</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">3-7 years</td><td style="text-align: left"> </td></tr> </table>   The Company periodically assesses the recoverability of property, plant and equipment and evaluates such assets for impairment whenever events or changes in circumstances indicate that the net carrying amount of an asset may not be recoverable. Asset impairment is determined to exist if estimated future cash flows, undiscounted and without interest charges, are less than the net carrying amount. Depreciation expense is computed on a straight-line basis over the estimate useful lives of the assets as follows:   <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="width: 45%; text-align: justify; padding-left: 5.4pt">Building and leasehold improvements</td><td style="width: 10%"> </td> <td style="width: 1%; text-align: left"> </td><td style="width: 43%; text-align: right">10-25 years</td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: justify; padding-left: 5.4pt">Machinery and equipment</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">5 years</td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: justify; padding-left: 5.4pt">Furniture and fixtures</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">3-7 years</td><td style="text-align: left"> </td></tr></table> Fair Value of Financial Instruments   The fair value of a financial instrument is the amount that could be received upon the sale of an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Financial assets are marked to bid prices and financial liabilities are marked to offer prices. Fair value measurements do not include transaction costs. A fair value hierarchy is used to prioritize the quality and reliability of the information used to determine fair values. Categorization within the fair value hierarchy is based on the lowest level of input that is significant to the fair value measurement. The fair value hierarchy is defined into the following three categories:   Level 1: Quoted market prices in active markets for identical assets or liabilities   Level 2: Observable market-based inputs or inputs that are corroborated by market data   Level 3: Unobservable inputs that are not corroborated by market data Stock-based Compensation   The Company adopted ASC 718 effective January 1, 2006 using the modified prospective method. Under this transition method, stock compensation expense includes compensation expense for all stock-based compensation awards granted on or after January 1, 2006, based on the grant-date fair value estimated in accordance with the provisions of ASC 718. Provision for Taxes   The Company applies ASC 740, which requires the asset and liability method of accounting for income taxes.  This method requires that the current or deferred tax consequences of all events recognized in the financial statements be measured by applying the provisions of enacted tax laws to determine the amount of taxes payable or refundable currently or in future years. Deferred tax assets are reviewed for recoverability and the Company records a valuation allowance to reduce its deferred tax assets when it is more likely than not that all or some portion of the deferred tax assets will not be recovered.    The Company adopted ASC 740, at the beginning of fiscal year 2008. This interpretation requires recognition and measurement of uncertain tax positions using a “more-likely-than-not” approach, requiring the recognition and measurement of uncertain tax positions. The adoption of ASC 740 had no material impact on the Company’s financial statements. Basic and Diluted Loss per Share   Basic and diluted loss per share is calculated by dividing the Company’s net loss applicable to common shareholders by the weighted average number of common shares during the period. Diluted earnings per share is calculated by dividing the Company’s net income available to common shareholders by the diluted weighted average number of shares outstanding during the year. The diluted weighted average number of shares outstanding is the basic weighted number of shares adjusted for any potentially dilutive debt or equity. The Company had 1,200,000 potential dilutive shares as of December 31, 2016 that were excluded as their effect was anti-dilutive. Reporting Segments   ASC 280 establishes standards for the way that public enterprises report information about operating segments in annual financial statements and requires reporting of selected information about operating segments in interim financial statements regarding products and services, geographic areas and major customers. ASC 280 defines operating segments as components of an enterprise about which separate financial information is available that is evaluated regularly by the chief operating decision maker in deciding how to allocate resources and in assessing performances.  Currently, ASC 280 has no effect on the Company’s consolidated financial statements as substantially all of the Company’s operations are conducted in one industry segment. Ceiling Test   In applying the full cost method, the Company performs an impairment test (ceiling test) at each reporting date, whereby the carrying value of property and equipment is compared to the value of its proved reserves discounted at a ten percent interest rate of future net revenues, based on current economic and operating conditions, plus the cost of properties not being amortized, plus the lower of cost or fair market value of unproved properties included in costs being amortized, less the income tax effects related to book and tax basis differences of the properties.  During the years ended December 31, 2016 and 2015, the Company had recorded $-0- and $404,837, respectively, of impairment expense in connection with the full cost ceiling test calculation. Asset Retirement Obligation   The Company follows ASC 410, Asset Retirement and Environmental Obligations which requires entities to record the fair value of a liability for asset retirement obligations (“ARO”) and recorded a corresponding increase in the carrying amount of the related long-lived asset. The asset retirement obligation primarily relates to the abandonment of oil and gas properties. The present value of the estimated asset retirement cost is capitalized as part of the carrying amount of oil and gas properties and is depleted over the useful life of the asset. The settlement date fair value is discounted at our credit adjusted risk-free rate in determining the abandonment liability. The abandonment liability is accreted with the passage of time to its expected settlement fair value. Revisions to such estimates are recorded as adjustments to ARO are charged to operations in the period in which they become known. At the time the abandonment cost is incurred, the Company is required to recognize a gain or loss if the actual costs do not equal the estimated costs included in ARO.   The ARO is based upon numerous estimates and assumptions, including future abandonment costs, future recoverable quantities of oil and gas, future inflation rates, and the credit adjusted risk free interest rate. Recent Accounting Pronouncements   Management has considered all recent accounting pronouncements issued since the last audit of its consolidated financial statements. The Company’s management believes that these recent pronouncements will not have a material effect on the Company’s consolidated financial statements. Oil and gas properties are stated at cost. As of December 31, 2016, and December 31, 2015, oil and gas properties, net consisted of the following:   <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="vertical-align: bottom"> <td> </td><td style="padding-bottom: 1pt"> </td> <td colspan="3" style="text-align: center; border-bottom: Black 1pt solid">December 31, 2016</td><td style="padding-bottom: 1pt"> </td> <td colspan="3" style="text-align: center; border-bottom: Black 1pt solid">December 31, 2015</td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="width: 56%; text-align: left">Unproved properties</td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">470,377</td><td style="width: 1%; text-align: left"> </td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">470,377</td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-bottom: 1pt">Impairment of oil and gas leases</td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left"> </td><td style="border-bottom: Black 1pt solid; text-align: right">(470,377</td><td style="padding-bottom: 1pt; text-align: left">)</td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left"> </td><td style="border-bottom: Black 1pt solid; text-align: right">(470,377</td><td style="padding-bottom: 1pt; text-align: left">)</td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-bottom: 2.5pt">Oil and gas properties, net</td><td style="padding-bottom: 2.5pt"> </td> <td style="border-bottom: Black 2.5pt double; text-align: left">$</td><td style="border-bottom: Black 2.5pt double; text-align: right">—  </td><td style="padding-bottom: 2.5pt; text-align: left"> </td><td style="padding-bottom: 2.5pt"> </td> <td style="border-bottom: Black 2.5pt double; text-align: left">$</td><td style="border-bottom: Black 2.5pt double; text-align: right">—  </td><td style="padding-bottom: 2.5pt; text-align: left"> </td></tr></table> Changes to the asset retirement obligation for the years ended December 31, 2016 and 2015 were as follows:   <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="vertical-align: bottom"> <td> </td><td style="padding-bottom: 1pt"> </td> <td colspan="3" style="text-align: center; border-bottom: Black 1pt solid">December 31, 2016</td><td style="padding-bottom: 1pt"> </td> <td colspan="3" style="text-align: center; border-bottom: Black 1pt solid">December 31, 2015</td></tr> <tr style="vertical-align: bottom"> <td> </td><td> </td> <td colspan="3"> </td><td> </td> <td colspan="3"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="width: 56%; padding-left: 5.4pt">Balance, beginning of period</td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">11,534</td><td style="width: 1%; text-align: left"> </td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">10,819</td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt">Liabilities incurred</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-bottom: 1pt; padding-left: 5.4pt">Accretion expense</td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left"> </td><td style="border-bottom: Black 1pt solid; text-align: right">789</td><td style="padding-bottom: 1pt; text-align: left"> </td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left"> </td><td style="border-bottom: Black 1pt solid; text-align: right">715</td><td style="padding-bottom: 1pt; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="padding-bottom: 2.5pt; padding-left: 5.4pt">Balance, end of period</td><td style="padding-bottom: 2.5pt"> </td> <td style="border-bottom: Black 2.5pt double; text-align: left">$</td><td style="border-bottom: Black 2.5pt double; text-align: right">12,323</td><td style="padding-bottom: 2.5pt; text-align: left"> </td><td style="padding-bottom: 2.5pt"> </td> <td style="border-bottom: Black 2.5pt double; text-align: left">$</td><td style="border-bottom: Black 2.5pt double; text-align: right">11,534</td><td style="padding-bottom: 2.5pt; text-align: left"> </td></tr></table> The provision for income taxes consists of the following:   <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="vertical-align: bottom"> <td> </td><td> </td> <td colspan="7" style="text-align: center">For the Years Ended</td></tr> <tr style="vertical-align: bottom"> <td> </td><td style="padding-bottom: 1pt"> </td> <td colspan="7" style="text-align: center; border-bottom: Black 1pt solid">December 31,</td></tr> <tr style="vertical-align: bottom"> <td> </td><td style="padding-bottom: 1pt"> </td> <td colspan="3" style="text-align: center; border-bottom: Black 1pt solid">2016</td><td style="padding-bottom: 1pt"> </td> <td colspan="3" style="text-align: center; border-bottom: Black 1pt solid">2015</td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="width: 56%; text-align: left; padding-left: 5.4pt">Current taxes</td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">(29,550</td><td style="width: 1%; text-align: left">)</td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">(173,192</td><td style="width: 1%; text-align: left">)</td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt">Impairment of oil and gas properties</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">137,645</td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-bottom: 1pt; padding-left: 5.4pt">Valuation allowance</td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left"> </td><td style="border-bottom: Black 1pt solid; text-align: right">29,550</td><td style="padding-bottom: 1pt; text-align: left"> </td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left"> </td><td style="border-bottom: Black 1pt solid; text-align: right">35,547</td><td style="padding-bottom: 1pt; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-bottom: 1pt; padding-left: 5.4pt">Total provision for income taxes</td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left">$</td><td style="border-bottom: Black 1pt solid; text-align: right">—  </td><td style="padding-bottom: 1pt; text-align: left"> </td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left">$</td><td style="border-bottom: Black 1pt solid; text-align: right">—  </td><td style="padding-bottom: 1pt; text-align: left"> </td></tr></table> The income tax provision differs from the amount of income tax determined by applying the U.S. federal and state income tax rates of 34% to pretax income from continuing operations for the years ended December 31, 2016 and 2015 due to the following:   <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="vertical-align: bottom"> <td> </td><td style="padding-bottom: 1pt"> </td> <td colspan="7" style="text-align: center; border-bottom: Black 1pt solid">December 31,</td></tr> <tr style="vertical-align: bottom"> <td> </td><td style="padding-bottom: 1pt"> </td> <td colspan="3" style="text-align: center; border-bottom: Black 1pt solid">2016</td><td style="padding-bottom: 1pt"> </td> <td colspan="3" style="text-align: center; border-bottom: Black 1pt solid">2015</td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="width: 56%; text-align: left; padding-left: 5.4pt">Loss carry forwards (expire through 2035)</td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">1,636,324</td><td style="width: 1%; text-align: left"> </td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">1,568,832</td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="padding-left: 5.4pt"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt">Total gross deferred tax asset</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">698,751</td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">718,676</td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-bottom: 1pt; padding-left: 5.4pt">Valuation allowance</td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left"> </td><td style="border-bottom: Black 1pt solid; text-align: right">(698,751</td><td style="padding-bottom: 1pt; text-align: left">)</td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left"> </td><td style="border-bottom: Black 1pt solid; text-align: right">(718,676</td><td style="padding-bottom: 1pt; text-align: left">)</td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-bottom: 1pt; padding-left: 5.4pt">Net deferred taxes</td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left">$</td><td style="border-bottom: Black 1pt solid; text-align: right">—  </td><td style="padding-bottom: 1pt; text-align: left"> </td><td style="padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; text-align: left">$</td><td style="border-bottom: Black 1pt solid; text-align: right">—  </td><td style="padding-bottom: 1pt; text-align: left"> </td></tr></table> The following table sets forth the Company's net proved reserves, including proved developed and proved undeveloped reserves, at December 31, 2016 and 2015, as pursuant to reserve reports prepared by the Company’s independent, certified petroleum engineer.    <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="text-align: center; background-color: White; vertical-align: bottom"> <td style="padding-bottom: 1pt; padding-left: 5.4pt"> </td><td style="font-weight: bold; padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; font-weight: bold"> </td><td style="border-bottom: Black 1pt solid; font-weight: bold">December 31, 2016</td><td style="padding-bottom: 1pt; font-weight: bold"> </td><td style="font-weight: bold; padding-bottom: 1pt"> </td> <td style="border-bottom: Black 1pt solid; font-weight: bold"> </td><td style="border-bottom: Black 1pt solid; font-weight: bold">December 31, 2015</td><td style="padding-bottom: 1pt; font-weight: bold"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="padding-left: 5.4pt"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt">Net Proved Developed Reserves:</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="width: 56%; text-align: left; padding-left: 5.4pt">   Crude oil (Bbls)</td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left"> </td><td style="width: 12%; text-align: right">—  </td><td style="width: 1%; text-align: left"> </td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left"> </td><td style="width: 12%; text-align: right">—  </td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt">   Natural gas (Mcf)</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt">   Oil equivalents (Boa)</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="padding-left: 5.4pt"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt">Net Proved Undeveloped Reserves:</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt">   Crude oil (Bbls)</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt">   Natural gas (Mcf)</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt">   Oil equivalents (Boe)</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="padding-left: 5.4pt"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt">Net Proved Developed and Undeveloped Reserves:</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt">   Crude oil (Bbls)</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt">   Natural gas (Mcf)</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt">   Oil equivalents (Boe)</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr></table> The following table sets forth the capitalized costs relating to the Company’s crude oil and natural gas producing activities at December 31, 2016 and 2015:   <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="vertical-align: bottom"> <td style="padding-bottom: 1pt"> </td><td style="font-weight: bold; padding-bottom: 1pt"> </td> <td colspan="3" style="font-weight: bold; text-align: center; border-bottom: Black 1pt solid">At December 31, 2016</td><td style="font-weight: bold; padding-bottom: 1pt"> </td> <td colspan="3" style="font-weight: bold; text-align: center; border-bottom: Black 1pt solid">At December 31, 2015</td></tr> <tr style="vertical-align: bottom"> <td> </td><td> </td> <td colspan="3"> </td><td> </td> <td colspan="3"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt">Proved leasehold costs</td><td> </td> <td style="text-align: left">$</td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left">$</td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="width: 56%; text-align: left; padding-left: 5.4pt">Costs of wells and development</td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left"> </td><td style="width: 12%; text-align: right">910,855</td><td style="width: 1%; text-align: left"> </td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left"> </td><td style="width: 12%; text-align: right">910,855</td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt">Capitalized asset retirement costs</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">9,860</td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">9,860</td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt">Total cost of oil and gas properties</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">920,715</td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">920,715</td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt; padding-bottom: 1pt">Accumulated depreciation, depletion, and impairment</td><td style="padding-bottom: 1pt"> </td> <td style="text-align: left; border-bottom: Black 1pt solid"> </td><td style="text-align: right; border-bottom: Black 1pt solid">(920,715</td><td style="text-align: left; padding-bottom: 1pt">)</td><td style="padding-bottom: 1pt"> </td> <td style="text-align: left; border-bottom: Black 1pt solid"> </td><td style="text-align: right; border-bottom: Black 1pt solid">(920,715</td><td style="text-align: left; padding-bottom: 1pt">)</td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt; padding-bottom: 2.5pt">Net Capitalized Costs</td><td style="padding-bottom: 2.5pt"> </td> <td style="text-align: left; border-bottom: Black 2.5pt double">$</td><td style="text-align: right; border-bottom: Black 2.5pt double">—  </td><td style="text-align: left; padding-bottom: 2.5pt"> </td><td style="padding-bottom: 2.5pt"> </td> <td style="text-align: left; border-bottom: Black 2.5pt double">$</td><td style="text-align: right; border-bottom: Black 2.5pt double">—  </td><td style="text-align: left; padding-bottom: 2.5pt"> </td></tr></table> The following table sets forth the costs incurred in the Company’s oil and gas property acquisition, exploration and development activities for the ended December 31, 2016 and 2015:   <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="text-align: center; background-color: White; vertical-align: bottom"> <td style="padding-left: 5.4pt; padding-bottom: 1pt"> </td><td style="font-weight: bold; padding-bottom: 1pt"> </td> <td style="font-weight: bold; padding-bottom: 1pt"> </td><td style="font-weight: bold; border-bottom: Black 1pt solid">For the Year Ended December 31, 2016</td><td style="font-weight: bold; padding-bottom: 1pt"> </td><td style="font-weight: bold; padding-bottom: 1pt"> </td> <td style="font-weight: bold; padding-bottom: 1pt"> </td><td style="font-weight: bold; border-bottom: Black 1pt solid">For the Year Ended December 31, 2015</td><td style="font-weight: bold; padding-bottom: 1pt"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="padding-left: 5.4pt"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="padding-left: 5.4pt">Acquisition of properties:</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="width: 56%; padding-left: 5.4pt">   Proved</td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">—  </td><td style="width: 1%; text-align: left"> </td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">—  </td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt">   Exploration costs</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt; padding-bottom: 1pt">   Development costs</td><td style="padding-bottom: 1pt"> </td> <td style="text-align: left; border-bottom: Black 1pt solid"> </td><td style="text-align: right; border-bottom: Black 1pt solid">—  </td><td style="text-align: left; padding-bottom: 1pt"> </td><td style="padding-bottom: 1pt"> </td> <td style="text-align: left; border-bottom: Black 1pt solid"> </td><td style="text-align: right; border-bottom: Black 1pt solid">—  </td><td style="text-align: left; padding-bottom: 1pt"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt; padding-bottom: 2.5pt">Net Capitalized Costs</td><td style="padding-bottom: 2.5pt"> </td> <td style="text-align: left; border-bottom: Black 2.5pt double">$</td><td style="text-align: right; border-bottom: Black 2.5pt double">—  </td><td style="text-align: left; padding-bottom: 2.5pt"> </td><td style="padding-bottom: 2.5pt"> </td> <td style="text-align: left; border-bottom: Black 2.5pt double">$</td><td style="text-align: right; border-bottom: Black 2.5pt double">—  </td><td style="text-align: left; padding-bottom: 2.5pt"> </td></tr></table> The following table sets forth the results of operations for oil and gas producing activities for the year ended December 31, 2016 and 2015:   <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="vertical-align: bottom"> <td style="padding-bottom: 1pt"> </td><td style="font-weight: bold; padding-bottom: 1pt"> </td> <td colspan="3" style="font-weight: bold; text-align: center; border-bottom: Black 1pt solid">For the Year Ended December 31, 2016</td><td style="font-weight: bold; padding-bottom: 1pt"> </td> <td colspan="3" style="font-weight: bold; text-align: center; border-bottom: Black 1pt solid">For the Year Ended December 31, 2015</td></tr> <tr style="vertical-align: bottom"> <td> </td><td> </td> <td colspan="3"> </td><td> </td> <td colspan="3"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="width: 56%; text-align: left; padding-left: 5.4pt">Crude oil and gas revenues</td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">—  </td><td style="width: 1%; text-align: left"> </td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">15,008</td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt">Production costs</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">(4,079</td><td style="text-align: left">)</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">(679</td><td style="text-align: left">)</td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt; padding-bottom: 1pt">Depreciation, depletion and accretion</td><td style="padding-bottom: 1pt"> </td> <td style="text-align: left; border-bottom: Black 1pt solid"> </td><td style="text-align: right; border-bottom: Black 1pt solid">(789</td><td style="text-align: left; padding-bottom: 1pt">)</td><td style="padding-bottom: 1pt"> </td> <td style="text-align: left; border-bottom: Black 1pt solid"> </td><td style="text-align: right; border-bottom: Black 1pt solid">(715</td><td style="text-align: left; padding-bottom: 1pt">)</td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt; padding-bottom: 2.5pt">Results of operations for producing activities, excluding corporate overhead</td><td style="padding-bottom: 2.5pt"> </td> <td style="text-align: left; border-bottom: Black 2.5pt double">$</td><td style="text-align: right; border-bottom: Black 2.5pt double">(4,868</td><td style="text-align: left; padding-bottom: 2.5pt">)</td><td style="padding-bottom: 2.5pt"> </td> <td style="text-align: left; border-bottom: Black 2.5pt double">$</td><td style="text-align: right; border-bottom: Black 2.5pt double">13,614</td><td style="text-align: left; padding-bottom: 2.5pt"> </td></tr></table> The following table sets forth the standardized measure of discounted future net cash flows from projected production of the Company’s oil and gas reserves as of December 31, 2016 and 2015:    <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="text-align: center; background-color: White; vertical-align: bottom"> <td style="text-indent: -8.1pt; padding-left: 8.1pt"> </td><td style="font-weight: bold"> </td> <td style="font-weight: bold"> </td><td style="font-weight: bold">December 31, 2016</td><td style="font-weight: bold"> </td><td style="font-weight: bold"> </td> <td style="font-weight: bold"> </td><td style="font-weight: bold">December 31, 2015</td><td style="font-weight: bold"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="padding-left: 5.4pt"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="width: 56%; text-align: left; padding-left: 5.4pt">Future cash inflows</td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">—  </td><td style="width: 1%; text-align: left"> </td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">—  </td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt">Future production and development costs</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt">Future income tax and insurance expense</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt">Future net cash inflows</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: left; padding-left: 5.4pt; padding-bottom: 1pt">10% annual discount for estimated timing of cash flows</td><td style="padding-bottom: 1pt"> </td> <td style="text-align: left; border-bottom: Black 1pt solid"> </td><td style="text-align: right; border-bottom: Black 1pt solid">—  </td><td style="text-align: left; padding-bottom: 1pt"> </td><td style="padding-bottom: 1pt"> </td> <td style="text-align: left; border-bottom: Black 1pt solid"> </td><td style="text-align: right; border-bottom: Black 1pt solid">—  </td><td style="text-align: left; padding-bottom: 1pt"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: left; padding-left: 5.4pt; padding-bottom: 2.5pt">Standardized measure of discounted future net cash flows</td><td style="padding-bottom: 2.5pt"> </td> <td style="text-align: left; border-bottom: Black 2.5pt double">$</td><td style="text-align: right; border-bottom: Black 2.5pt double">—  </td><td style="text-align: left; padding-bottom: 2.5pt"> </td><td style="padding-bottom: 2.5pt"> </td> <td style="text-align: left; border-bottom: Black 2.5pt double">$</td><td style="text-align: right; border-bottom: Black 2.5pt double">—  </td><td style="text-align: left; padding-bottom: 2.5pt"> </td></tr></table> The following table sets forth the changes in the standardized measure of discounted future net cash flows for the year ended December 31, 2016 and 2015:   <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="text-align: center; background-color: White; vertical-align: bottom"> <td style="padding-left: 5.4pt; padding-bottom: 1pt"> </td><td style="font-weight: bold; padding-bottom: 1pt"> </td> <td style="font-weight: bold; padding-bottom: 1pt"> </td><td style="font-weight: bold; border-bottom: Black 1pt solid">December 31, 2016</td><td style="font-weight: bold; padding-bottom: 1pt"> </td><td style="font-weight: bold; padding-bottom: 1pt"> </td> <td style="font-weight: bold; padding-bottom: 1pt"> </td><td style="font-weight: bold; border-bottom: Black 1pt solid">December 31, 2015</td><td style="font-weight: bold; padding-bottom: 1pt"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: justify; padding-left: 5.4pt"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="width: 56%; text-align: justify; padding-left: 5.4pt">Beginning of period</td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">—  </td><td style="width: 1%; text-align: left"> </td><td style="width: 8%"> </td> <td style="width: 1%; text-align: left">$</td><td style="width: 12%; text-align: right">—  </td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: justify; padding-left: 5.4pt">  Revenues less production and other costs</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: justify; padding-left: 5.4pt">  Changes in price, net of production costs</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: justify; padding-left: 5.4pt">  Development costs incurred</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: justify; padding-left: 5.4pt">  Net changes in future development costs</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: justify; padding-left: 5.4pt">  Purchases of reserves in place</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: justify; padding-left: 5.4pt">  Accretion of discount</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: justify; padding-left: 5.4pt">  Net change in income taxes</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">—  </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: justify; padding-left: 5.4pt; padding-bottom: 1pt">  Timing differences and other</td><td style="padding-bottom: 1pt"> </td> <td style="text-align: left; border-bottom: Black 1pt solid"> </td><td style="text-align: right; border-bottom: Black 1pt solid">—  </td><td style="text-align: left; padding-bottom: 1pt"> </td><td style="padding-bottom: 1pt"> </td> <td style="text-align: left; border-bottom: Black 1pt solid"> </td><td style="text-align: right; border-bottom: Black 1pt solid">—  </td><td style="text-align: left; padding-bottom: 1pt"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: justify; padding-left: 5.4pt; padding-bottom: 2.5pt">End of period</td><td style="padding-bottom: 2.5pt"> </td> <td style="text-align: left; border-bottom: Black 2.5pt double">$</td><td style="text-align: right; border-bottom: Black 2.5pt double">—  </td><td style="text-align: left; padding-bottom: 2.5pt"> </td><td style="padding-bottom: 2.5pt"> </td> <td style="text-align: left; border-bottom: Black 2.5pt double">$</td><td style="text-align: right; border-bottom: Black 2.5pt double">—  </td><td style="text-align: left; padding-bottom: 2.5pt"> </td></tr></table> Impairment of Long-Lived Assets   The Company follows the provisions of ASC 360 for its long-lived assets.  The Company’s long-lived assets, which include test equipment and purchased intellectual property rights, are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable.   The Company assesses the recoverability of its long-lived assets by comparing the projected undiscounted net cash flows associated with the related long-lived asset or group of long-lived assets over their remaining estimated useful lives against their respective carrying amounts.  Impairment, if any, is based on the excess of the carrying amount over the fair value of those assets.  Fair value is generally determined using the asset’s expected future discounted cash flows or market value, if readily determinable.  If long-lived assets are determined to be recoverable, but the newly determined remaining estimated useful lives are shorter than originally estimated, the net book values of the long-lived assets are depreciated over the newly determined remaining estimated useful lives.     The Company recognized impairment expense totaling $-0- and $404,837 for the years ended December 31, 2016 and 2015, respectively. Oil and Gas Properties   The Company uses the full cost method of accounting for oil and natural gas properties. Under this method, all acquisition, exploration and development costs, including certain payroll, asset retirement costs, other internal costs, and interest incurred for the purpose of finding oil and natural gas reserves, are capitalized. Internal costs that are capitalized are directly attributable to acquisition, exploration and development activities and do not include costs related to production, general corporate overhead or similar activities. Costs associated with production and general corporate activities are expensed in the period incurred. Proceeds from the sale of oil and natural gas properties are applied to reduce the capitalized costs of oil and natural gas properties unless the sale would significantly alter the relationship between capitalized costs and proved reserves, in which case a gain or loss is recognized.   Capitalized costs associated with impaired properties and capitalized costs related to properties having proved reserves, plus the estimated future development costs, and asset retirement costs under Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic 410 “Asset Retirement and Environmental Obligations” (FASB ASC 410), are amortized using the unit-of-production method based on proved reserves. Capitalized costs of oil and natural gas properties, net of accumulated amortization and deferred income taxes, are limited to the total of estimated future net cash flows from proved oil and natural gas reserves, discounted at ten percent, plus the cost of unevaluated properties.  Under certain specific conditions, companies could elect to use subsequent prices for determining the estimated future net cash flows. The use of subsequent pricing is no longer allowed. There are many factors, including global events that may influence the production, processing, marketing and price of oil and natural gas. A reduction in the valuation of oil and natural gas properties resulting from declining prices or production could adversely impact depletion rates and capitalized cost limitations. Capitalized costs associated with properties that have not been evaluated through drilling or seismic analysis, including exploration wells in progress at December 31, 2016, are excluded from the unit-of-production amortization. Exclusions are adjusted annually based on drilling results and interpretative analysis.    Sales of oil and natural gas properties are accounted for as adjustments to the net full cost pool with no gain or loss recognized, unless the adjustment would significantly alter the relationship between capitalized costs and proved reserves. If it is determined that the relationship is significantly altered, the corresponding gain or loss will be recognized in the statements of operations.    Costs of oil and gas properties are depleted using the unit-of-production method. For the years ended December 31, 2016 and 2015, the Company recognized $-0- of depletion expense related to oil and gas production during the period. NOTE 1 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES   Business Activity   Tiger Oil and Energy, Inc., formerly UTeC, Inc., is a Nevada corporation organized on November 8, 1993 as a “For Profit” corporation for the purpose of engaging in any lawful activity.   On January 10, 2007, the Company purchased 100% of the shares of UTeC Corporation, Inc.   In 2007, the Company licensed technology covering the use of cold plasma oxidizer technology for the destruction of solid and liquid hazardous chemicals and biologicals.  During 2007 and 2008, the Company worked to validate the technology and prepare a business plan for its commercialization.   In April 2009, the Company divested its commercial explosives development, analysis, testing and manufacturing business to eliminate the need to inject new capital into the Company to support this business, and concentrate on raising the funds necessary to commercialize its hazardous waste destruction business.  At this time, the Company re-entered the development stage.   Prior to the divestiture, the Company’s business was to offer state of the art testing and analysis to clients worldwide.  The Company operated a chemical research and development laboratory near Riverton, Kansas, which specialized in commercial explosives development and analysis. The Company also operated a destructive test facility near Hallowell, Kansas, which specialized in determining the detonating characteristics of commercial explosives.   On October 1, 2009 the Company entered into an agreement to purchase 100% of the outstanding shares of C2R Energy Commodities, Inc., a Nevada corporation, in exchange for 4,050,000 shares of the Company’s restricted common stock.  The Company entered into this agreement due primarily to the fact that C2R owned certain intellectual property that the Company wished to acquire.   On October 29, 2010, the Company acquired all of the membership interest in Jett Rink Oil, LLC (“Jett Rink”) in exchange for 10,000,000 shares of the Company’s Common Stock.  Jett Rink is involved in the business relating to the exploration, development and production of oil and gas in the United States. At the closing of the Exchange Agreement, Jett Rink became a wholly-owned subsidiary of the Company and the Company acquired the business and operations of Jett Rink.   Basis of Presentation   The accompanying audited consolidated financial statements and related notes include the activity of the Company and its two wholly-owned subsidiaries, C2R Energy Commodities, Inc. and Jett Rink Oil, LLC and have been prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”) and with the rules and regulations of the United States Securities and Exchange Commission (“SEC”) to Form 10-K. All inter-company balances and transactions have been eliminated.   Reclassification   Certain amounts in the prior period financial statements have been reclassified to conform to the current period presentation.   These reclassifications had no effect on reported losses.   Consolidation    The accompanying consolidated financial statements included all of the accounts of the Company and its wholly-owned subsidiaries, C2R, Inc., a Nevada Corporation, and Jett Rink Oil, LLC, a Kansas Limited Liability Company. All intercompany transactions have been eliminated.   Accounting Method   The Company’s financial statements are prepared using the accrual method of accounting.  The Company has elected a December 31 year-end.   Use of Estimates   The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period.  Actual results could differ from those estimates.   Cash and Cash Equivalents   For purposes of the Statement of Cash Flows, the Company considers all highly liquid instruments purchased with a maturity of three months or less to be cash equivalents to the extent the funds are not being held for investment purposes.  The Company at times may maintain a cash balance in excess of insured limits.   Property, Plant and Equipment   Property and equipment are stated at cost.  Major additions and improvements are capitalized in the month following the month in which the assets or improvement are deemed to be placed in service. Maintenance and repairs are expensed as incurred. Upon disposition, the net book value is eliminated from the accounts, with the resultant gain or loss reflected in operations. Depreciation expense is computed on a straight-line basis over the estimate useful lives of the assets as follows:   <table cellpadding="0" cellspacing="0" style="border-collapse: collapse; width: 100%; font: 10pt Times New Roman, Times, Serif"> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="width: 45%; text-align: justify; padding-left: 5.4pt">Building and leasehold improvements</td><td style="width: 10%"> </td> <td style="width: 1%; text-align: left"> </td><td style="width: 43%; text-align: right">10-25 years</td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: justify; padding-left: 5.4pt">Machinery and equipment</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">5 years</td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="text-align: justify; padding-left: 5.4pt">Furniture and fixtures</td><td> </td> <td style="text-align: left"> </td><td style="text-align: right">3-7 years</td><td style="text-align: left"> </td></tr> </table>   The Company periodically assesses the recoverability of property, plant and equipment and evaluates such assets for impairment whenever events or changes in circumstances indicate that the net carrying amount of an asset may not be recoverable. Asset impairment is determined to exist if estimated future cash flows, undiscounted and without interest charges, are less than the net carrying amount.   Impairment of Long-Lived Assets   The Company follows the provisions of ASC 360 for its long-lived assets.  The Company’s long-lived assets, which include test equipment and purchased intellectual property rights, are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable.   The Company assesses the recoverability of its long-lived assets by comparing the projected undiscounted net cash flows associated with the related long-lived asset or group of long-lived assets over their remaining estimated useful lives against their respective carrying amounts.  Impairment, if any, is based on the excess of the carrying amount over the fair value of those assets.  Fair value is generally determined using the asset’s expected future discounted cash flows or market value, if readily determinable.  If long-lived assets are determined to be recoverable, but the newly determined remaining estimated useful lives are shorter than originally estimated, the net book values of the long-lived assets are depreciated over the newly determined remaining estimated useful lives.     The Company recognized impairment expense totaling $-0- and $404,837 for the years ended December 31, 2016 and 2015, respectively.   Fair Value of Financial Instruments   The fair value of a financial instrument is the amount that could be received upon the sale of an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Financial assets are marked to bid prices and financial liabilities are marked to offer prices. Fair value measurements do not include transaction costs. A fair value hierarchy is used to prioritize the quality and reliability of the information used to determine fair values. Categorization within the fair value hierarchy is based on the lowest level of input that is significant to the fair value measurement. The fair value hierarchy is defined into the following three categories:   Level 1: Quoted market prices in active markets for identical assets or liabilities   Level 2: Observable market-based inputs or inputs that are corroborated by market data   Level 3: Unobservable inputs that are not corroborated by market data   Stock-based Compensation   The Company adopted ASC 718 effective January 1, 2006 using the modified prospective method. Under this transition method, stock compensation expense includes compensation expense for all stock-based compensation awards granted on or after January 1, 2006, based on the grant-date fair value estimated in accordance with the provisions of ASC 718.   Provision for Taxes   The Company applies ASC 740, which requires the asset and liability method of accounting for income taxes.  This method requires that the current or deferred tax consequences of all events recognized in the financial statements be measured by applying the provisions of enacted tax laws to determine the amount of taxes payable or refundable currently or in future years. Deferred tax assets are reviewed for recoverability and the Company records a valuation allowance to reduce its deferred tax assets when it is more likely than not that all or some portion of the deferred tax assets will not be recovered.    The Company adopted ASC 740, at the beginning of fiscal year 2008. This interpretation requires recognition and measurement of uncertain tax positions using a “more-likely-than-not” approach, requiring the recognition and measurement of uncertain tax positions. The adoption of ASC 740 had no material impact on the Company’s financial statements.     Basic and Diluted Loss per Share   Basic and diluted loss per share is calculated by dividing the Company’s net loss applicable to common shareholders by the weighted average number of common shares during the period. Diluted earnings per share is calculated by dividing the Company’s net income available to common shareholders by the diluted weighted average number of shares outstanding during the year. The diluted weighted average number of shares outstanding is the basic weighted number of shares adjusted for any potentially dilutive debt or equity. The Company had 1,200,000 potential dilutive shares as of December 31, 2016 that were excluded as their effect was anti-dilutive.   Reporting Segments   ASC 280 establishes standards for the way that public enterprises report information about operating segments in annual financial statements and requires reporting of selected information about operating segments in interim financial statements regarding products and services, geographic areas and major customers. ASC 280 defines operating segments as components of an enterprise about which separate financial information is available that is evaluated regularly by the chief operating decision maker in deciding how to allocate resources and in assessing performances.  Currently, ASC 280 has no effect on the Company’s consolidated financial statements as substantially all of the Company’s operations are conducted in one industry segment.   Oil and Gas Properties   The Company uses the full cost method of accounting for oil and natural gas properties. Under this method, all acquisition, exploration and development costs, including certain payroll, asset retirement costs, other internal costs, and interest incurred for the purpose of finding oil and natural gas reserves, are capitalized. Internal costs that are capitalized are directly attributable to acquisition, exploration and development activities and do not include costs related to production, general corporate overhead or similar activities. Costs associated with production and general corporate activities are expensed in the period incurred. Proceeds from the sale of oil and natural gas properties are applied to reduce the capitalized costs of oil and natural gas properties unless the sale would significantly alter the relationship between capitalized costs and proved reserves, in which case a gain or loss is recognized.   Capitalized costs associated with impaired properties and capitalized costs related to properties having proved reserves, plus the estimated future development costs, and asset retirement costs under Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic 410 “Asset Retirement and Environmental Obligations” (FASB ASC 410), are amortized using the unit-of-production method based on proved reserves. Capitalized costs of oil and natural gas properties, net of accumulated amortization and deferred income taxes, are limited to the total of estimated future net cash flows from proved oil and natural gas reserves, discounted at ten percent, plus the cost of unevaluated properties.  Under certain specific conditions, companies could elect to use subsequent prices for determining the estimated future net cash flows. The use of subsequent pricing is no longer allowed. There are many factors, including global events that may influence the production, processing, marketing and price of oil and natural gas. A reduction in the valuation of oil and natural gas properties resulting from declining prices or production could adversely impact depletion rates and capitalized cost limitations. Capitalized costs associated with properties that have not been evaluated through drilling or seismic analysis, including exploration wells in progress at December 31, 2016, are excluded from the unit-of-production amortization. Exclusions are adjusted annually based on drilling results and interpretative analysis.    Sales of oil and natural gas properties are accounted for as adjustments to the net full cost pool with no gain or loss recognized, unless the adjustment would significantly alter the relationship between capitalized costs and proved reserves. If it is determined that the relationship is significantly altered, the corresponding gain or loss will be recognized in the statements of operations.    Costs of oil and gas properties are depleted using the unit-of-production method. For the years ended December 31, 2016 and 2015, the Company recognized $-0- of depletion expense related to oil and gas production during the period.   Ceiling Test   In applying the full cost method, the Company performs an impairment test (ceiling test) at each reporting date, whereby the carrying value of property and equipment is compared to the value of its proved reserves discounted at a ten percent interest rate of future net revenues, based on current economic and operating conditions, plus the cost of properties not being amortized, plus the lower of cost or fair market value of unproved properties included in costs being amortized, less the income tax effects related to book and tax basis differences of the properties.  During the years ended December 31, 2016 and 2015, the Company had recorded $-0- and $404,837, respectively, of impairment expense in connection with the full cost ceiling test calculation.   Asset Retirement Obligation   The Company follows ASC 410, Asset Retirement and Environmental Obligations which requires entities to record the fair value of a liability for asset retirement obligations (“ARO”) and recorded a corresponding increase in the carrying amount of the related long-lived asset. The asset retirement obligation primarily relates to the abandonment of oil and gas properties. The present value of the estimated asset retirement cost is capitalized as part of the carrying amount of oil and gas properties and is depleted over the useful life of the asset. The settlement date fair value is discounted at our credit adjusted risk-free rate in determining the abandonment liability. The abandonment liability is accreted with the passage of time to its expected settlement fair value. Revisions to such estimates are recorded as adjustments to ARO are charged to operations in the period in which they become known. At the time the abandonment cost is incurred, the Company is required to recognize a gain or loss if the actual costs do not equal the estimated costs included in ARO.   The ARO is based upon numerous estimates and assumptions, including future abandonment costs, future recoverable quantities of oil and gas, future inflation rates, and the credit adjusted risk free interest rate.   Recent Accounting Pronouncements   Management has considered all recent accounting pronouncements issued since the last audit of its consolidated financial statements. 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Document and Entity Information - USD ($)
12 Months Ended

Dec. 31, 2016

Apr. 11, 2017

Jun. 30, 2016

Document And Entity Information

Entity Registrant Name Tiger Oil & Energy, Inc.

Entity Central Index Key 0001386018

Document Type 10-K

Document Period End Date Dec. 31, 2016

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Consolidated Balance Sheets - USD ($)

Dec. 31, 2016

Dec. 31, 2015

CURRENT ASSETS

Cash and cash equivalents $ 272 $ 15,047

Prepaid expenses and deposits 200 200

Total Current Assets 472 15,247

OTHER ASSETS

Oil and gas properties, net (full cost method)

TOTAL ASSETS 472 15,247

CURRENT LIABILITIES

Accounts payable and accrued expenses 114,380 82,978

Accounts payable - related party 33,000 16,000

Notes payable 5,200

Notes payable - related party 61,500 35,000

Convertible notes payable 600,000 600,000

Total Current Liabilities 808,880 739,178

LONG-TERM LIABILITIES

Asset retirement obligation 12,323 11,534

Total Long-Term Liabilities 12,323 11,534

TOTAL LIABILITIES 821,203 750,712

STOCKHOLDERS' DEFICIT

Preferred stock - 1,000,000 shares authorized, $0.001 par value; 42,013 issued and outstanding 42 42

Common stock - 74,000,000 shares authorized, $0.001 par value; 42,728,159 issued and outstanding 42,728 42,728

Additional paid-in capital 4,676,821 4,675,176

Accumulated deficit (5,540,322) (5,453,411)

Total Stockholders' Deficit (820,731) (735,465)

TOTAL LIABILITIES AND STOCKHOLDERS' DEFICIT $ 472 $ 15,247

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Consolidated Balance Sheets (Parenthetical) - $ / shares

Dec. 31, 2016

Dec. 31, 2015

Statement of Financial Position [Abstract]

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Preferred stock, par value per share $ 0.001 $ 0.001

Preferred stock, shares issued 42,013 42,013

Preferred stock, shares outstanding 42,013 42,013

Common stock, shares authorized 74,000,000 74,000,000

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Consolidated Statements Of Operations - USD ($)
12 Months Ended

Dec. 31, 2016

Dec. 31, 2015

Income Statement [Abstract]

REVENUES $ 15,008

OPERATING EXPENSES

Lease operating expense 4,079 679

Accretion expense 789 715

Legal and professional 68,882 46,059

Impairment of oil and gas properties 404,837

General and administrative 36,840 38,365

Total Operating Expenses 110,590 490,655

LOSS FROM OPERATIONS (110,590) (475,647)

OTHER INCOME (EXPENSE)

Interest expense 35,005 33,741

Gain on settlement of debt 58,684

Total Other Income (Expense) 23,679 (33,741)

LOSS BEFORE TAXES (86,911) (509,388)

Provision for income taxes

NET LOSS $ (86,911) $ (509,388)

BASIC AND DILUTED LOSS PER SHARE $ (0.00) $ (0.01)

BASIC AND DILUTED WEIGHTED AVERAGE NUMBER OF SHARES OUTSTANDING 42,728,159 42,728,159

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Consolidated Statement Of Stockholders' Deficit - USD ($)

Preferred Stock [Member]

Common Stock [Member]

Additional Paid-In Capital [Member]

Accumulated Deficit [Member]

Total

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Consolidated Statements Of Cash Flows - USD ($)
12 Months Ended

Dec. 31, 2016

Dec. 31, 2015

OPERATING ACTIVITIES

Net loss $ (86,911) $ (509,388)

Adjustments to Reconcile Net Loss to Net Cash Used by Operating Activities:

Depreciation, amortization and accretion expense 789 715

Gain on property settlement 58,684

Impairment of oil and gas properties 404,837

Amortization of debt discount 3,288

Changes in operating assets and liabilities:

Accounts payable and accrued liabilities 32,847 48,569

Accounts payable - related party 17,000 10,000

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INVESTING ACTIVITIES

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FINANCING ACTIVITIES

Proceeds from notes payable - related party 66,500 40,000

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Repayments of notes payable - related party 40,000

Net Cash Provided by Financing Activities 21,500 40,000

NET INCREASE (DECREASE) IN CASH (14,775) (1,979)

CASH AT BEGINNING OF PERIOD 15,047 17,026

CASH AT END OF PERIOD 272 15,047

SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION

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Summary Of Significant Accounting Policies
12 Months Ended

Dec. 31, 2016

Accounting Policies [Abstract]

Summary of Significant Accounting Policies
NOTE 1 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Business Activity

Tiger Oil and Energy, Inc., formerly UTeC, Inc., is a Nevada corporation organized on November 8, 1993 as a “For Profit” corporation for the purpose of engaging in any lawful activity. On January 10, 2007, the Company purchased 100% of the shares of UTeC Corporation, Inc. In 2007, the Company licensed technology covering the use of cold plasma oxidizer technology for the destruction of solid and liquid hazardous chemicals and biologicals. During 2007 and 2008, the Company worked to validate the technology and prepare a business plan for its commercialization.

In April 2009, the Company divested its commercial explosives development, analysis, testing and manufacturing business to eliminate the need to inject new capital into the Company to support this business, and concentrate on raising the funds necessary to commercialize its hazardous waste destruction business. At this time, the Company re-entered the development stage.

Prior to the divestiture, the Company’s business was to offer state of the art testing and analysis to clients worldwide. The Company operated a chemical research and development laboratory near Riverton, Kansas, which specialized in commercial explosives development and analysis. The Company also operated a destructive test facility near Hallowell, Kansas, which specialized in determining the detonating characteristics of commercial explosives.

On October 1, 2009 the Company entered into an agreement to purchase 100% of the outstanding shares of C2R Energy Commodities, Inc., a Nevada corporation, in exchange for 4,050,000 shares of the Company’s restricted common stock. The Company entered into this agreement due primarily to the fact that C2R owned certain intellectual property that the Company wished to acquire.

On October 29, 2010, the Company acquired all of the membership interest in Jett Rink Oil, LLC (“Jett Rink”) in exchange for 10,000,000 shares of the Company’s Common Stock. Jett Rink is involved in the business relating to the exploration, development and production of oil and gas in the United States. At the closing of the Exchange Agreement, Jett Rink became a wholly-owned subsidiary of the Company and the Company acquired the business and operations of Jett Rink.

Basis of Presentation

The accompanying audited consolidated financial statements and related notes include the activity of the Company and its two wholly-owned subsidiaries, C2R Energy Commodities, Inc. and Jett Rink Oil, LLC and have been prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”) and with the rules and regulations of the United States Securities and Exchange Commission (“SEC”) to Form 10-K. All inter-company balances and transactions have been eliminated.

Reclassification

Certain amounts in the prior period financial statements have been reclassified to conform to the current period presentation. These reclassifications had no effect on reported losses.

Consolidation

The accompanying consolidated financial statements included all of the accounts of the Company and its wholly-owned subsidiaries, C2R, Inc., a Nevada Corporation, and Jett Rink Oil, LLC, a Kansas Limited Liability Company. All intercompany transactions have been eliminated.

Accounting Method

The Company’s financial statements are prepared using the accrual method of accounting. The Company has elected a December 31 year-end.

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

Cash and Cash Equivalents

For purposes of the Statement of Cash Flows, the Company considers all highly liquid instruments purchased with a maturity of three months or less to be cash equivalents to the extent the funds are not being held for investment purposes. The Company at times may maintain a cash balance in excess of insured limits.

Property, Plant and Equipment

Property and equipment are stated at cost. Major additions and improvements are capitalized in the month following the month in which the assets or improvement are deemed to be placed in service. Maintenance and repairs are expensed as incurred. Upon disposition, the net book value is eliminated from the accounts, with the resultant gain or loss reflected in operations. Depreciation expense is computed on a straight-line basis over the estimate useful lives of the assets as follows:

Building and leasehold improvements 10-25 years

Machinery and equipment 5 years

Furniture and fixtures 3-7 years

The Company periodically assesses the recoverability of property, plant and equipment and evaluates such assets for impairment whenever events or changes in circumstances indicate that the net carrying amount of an asset may not be recoverable. Asset impairment is determined to exist if estimated future cash flows, undiscounted and without interest charges, are less than the net carrying amount.

Impairment of Long-Lived Assets

The Company follows the provisions of ASC 360 for its long-lived assets. The Company’s long-lived assets, which include test equipment and purchased intellectual property rights, are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable.

The Company assesses the recoverability of its long-lived assets by comparing the projected undiscounted net cash flows associated with the related long-lived asset or group of long-lived assets over their remaining estimated useful lives against their respective carrying amounts. Impairment, if any, is based on the excess of the carrying amount over the fair value of those assets. Fair value is generally determined using the asset’s expected future discounted cash flows or market value, if readily determinable. If long-lived assets are determined to be recoverable, but the newly determined remaining estimated useful lives are shorter than originally estimated, the net book values of the long-lived assets are depreciated over the newly determined remaining estimated useful lives.

The Company recognized impairment expense totaling $-0- and $404,837 for the years ended December 31, 2016 and 2015, respectively.

Fair Value of Financial Instruments

The fair value of a financial instrument is the amount that could be received upon the sale of an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Financial assets are marked to bid prices and financial liabilities are marked to offer prices. Fair value measurements do not include transaction costs. A fair value hierarchy is used to prioritize the quality and reliability of the information used to determine fair values. Categorization within the fair value hierarchy is based on the lowest level of input that is significant to the fair value measurement. The fair value hierarchy is defined into the following three categories:

Level 1: Quoted market prices in active markets for identical assets or liabilities

Level 2: Observable market-based inputs or inputs that are corroborated by market data

Level 3: Unobservable inputs that are not corroborated by market data

Stock-based Compensation

The Company adopted ASC 718 effective January 1, 2006 using the modified prospective method. Under this transition method, stock compensation expense includes compensation expense for all stock-based compensation awards granted on or after January 1, 2006, based on the grant-date fair value estimated in accordance with the provisions of ASC 718.

Provision for Taxes

The Company applies ASC 740, which requires the asset and liability method of accounting for income taxes. This method requires that the current or deferred tax consequences of all events recognized in the financial statements be measured by applying the provisions of enacted tax laws to determine the amount of taxes payable or refundable currently or in future years. Deferred tax assets are reviewed for recoverability and the Company records a valuation allowance to reduce its deferred tax assets when it is more likely than not that all or some portion of the deferred tax assets will not be recovered.

The Company adopted ASC 740, at the beginning of fiscal year 2008. This interpretation requires recognition and measurement of uncertain tax positions using a “more-likely-than-not” approach, requiring the recognition and measurement of uncertain tax positions. The adoption of ASC 740 had no material impact on the Company’s financial statements.



Basic and Diluted Loss per Share

Basic and diluted loss per share is calculated by dividing the Company’s net loss applicable to common shareholders by the weighted average number of common shares during the period. Diluted earnings per share is calculated by dividing the Company’s net income available to common shareholders by the diluted weighted average number of shares outstanding during the year. The diluted weighted average number of shares outstanding is the basic weighted number of shares adjusted for any potentially dilutive debt or equity. The Company had 1,200,000 potential dilutive shares as of December 31, 2016 that were excluded as their effect was anti-dilutive.

Reporting Segments

ASC 280 establishes standards for the way that public enterprises report information about operating segments in annual financial statements and requires reporting of selected information about operating segments in interim financial statements regarding products and services, geographic areas and major customers. ASC 280 defines operating segments as components of an enterprise about which separate financial information is available that is evaluated regularly by the chief operating decision maker in deciding how to allocate resources and in assessing performances. Currently, ASC 280 has no effect on the Company’s consolidated financial statements as substantially all of the Company’s operations are conducted in one industry segment.

Oil and Gas Properties

The Company uses the full cost method of accounting for oil and natural gas properties. Under this method, all acquisition, exploration and development costs, including certain payroll, asset retirement costs, other internal costs, and interest incurred for the purpose of finding oil and natural gas reserves, are capitalized. Internal costs that are capitalized are directly attributable to acquisition, exploration and development activities and do not include costs related to production, general corporate overhead or similar activities. Costs associated with production and general corporate activities are expensed in the period incurred. Proceeds from the sale of oil and natural gas properties are applied to reduce the capitalized costs of oil and natural gas properties unless the sale would significantly alter the relationship between capitalized costs and proved reserves, in which case a gain or loss is recognized.

Capitalized costs associated with impaired properties and capitalized costs related to properties having proved reserves, plus the estimated future development costs, and asset retirement costs under Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic 410 “Asset Retirement and Environmental Obligations” (FASB ASC 410), are amortized using the unit-of-production method based on proved reserves. Capitalized costs of oil and natural gas properties, net of accumulated amortization and deferred income taxes, are limited to the total of estimated future net cash flows from proved oil and natural gas reserves, discounted at ten percent, plus the cost of unevaluated properties. Under certain specific conditions, companies could elect to use subsequent prices for determining the estimated future net cash flows. The use of subsequent pricing is no longer allowed. There are many factors, including global events that may influence the production, processing, marketing and price of oil and natural gas. A reduction in the valuation of oil and natural gas properties resulting from declining prices or production could adversely impact depletion rates and capitalized cost limitations. Capitalized costs associated with properties that have not been evaluated through drilling or seismic analysis, including exploration wells in progress at December 31, 2016, are excluded from the unit-of-production amortization. Exclusions are adjusted annually based on drilling results and interpretative analysis.

Sales of oil and natural gas properties are accounted for as adjustments to the net full cost pool with no gain or loss recognized, unless the adjustment would significantly alter the relationship between capitalized costs and proved reserves. If it is determined that the relationship is significantly altered, the corresponding gain or loss will be recognized in the statements of operations.



Costs of oil and gas properties are depleted using the unit-of-production method. For the years ended December 31, 2016 and 2015, the Company recognized $-0- of depletion expense related to oil and gas production during the period.

Ceiling Test

In applying the full cost method, the Company performs an impairment test (ceiling test) at each reporting date, whereby the carrying value of property and equipment is compared to the value of its proved reserves discounted at a ten percent interest rate of future net revenues, based on current economic and operating conditions, plus the cost of properties not being amortized, plus the lower of cost or fair market value of unproved properties included in costs being amortized, less the income tax effects related to book and tax basis differences of the properties. During the years ended December 31, 2016 and 2015, the Company had recorded $-0- and $404,837, respectively, of impairment expense in connection with the full cost ceiling test calculation.

Asset Retirement Obligation

The Company follows ASC 410, Asset Retirement and Environmental Obligations which requires entities to record the fair value of a liability for asset retirement obligations (“ARO”) and recorded a corresponding increase in the carrying amount of the related long-lived asset. The asset retirement obligation primarily relates to the abandonment of oil and gas properties. The present value of the estimated asset retirement cost is capitalized as part of the carrying amount of oil and gas properties and is depleted over the useful life of the asset. The settlement date fair value is discounted at our credit adjusted risk-free rate in determining the abandonment liability. The abandonment liability is accreted with the passage of time to its expected settlement fair value. Revisions to such estimates are recorded as adjustments to ARO are charged to operations in the period in which they become known. At the time the abandonment cost is incurred, the Company is required to recognize a gain or loss if the actual costs do not equal the estimated costs included in ARO.

The ARO is based upon numerous estimates and assumptions, including future abandonment costs, future recoverable quantities of oil and gas, future inflation rates, and the credit adjusted risk free interest rate.

Recent Accounting Pronouncements

Management has considered all recent accounting pronouncements issued since the last audit of its consolidated financial statements. The Company’s management believes that these recent pronouncements will not have a material effect on the Company’s consolidated financial statements.

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Going Concern
12 Months Ended

Dec. 31, 2016

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Going Concern
NOTE 2 - GOING CONCERN

The Company's financial statements are prepared using generally accepted accounting principles in the United States of America applicable to a going concern which contemplates the realization of assets and liquidation of liabilities in the normal course of business. The Company has not yet established an ongoing source of revenues sufficient to cover its operating costs and allow it to continue as a going concern. The ability of the Company to continue as a going concern is dependent on the Company obtaining adequate capital to fund operating losses until it becomes profitable. If the Company is unable to obtain adequate capital, it could be forced to cease operations.

In order to continue as a going concern, the Company will need, among other things, additional capital resources. Management's plan is to obtain such resources for the Company by obtaining capital from management and significant shareholders sufficient to meet its minimal operating expenses and seeking equity and/or debt financing. However management cannot provide any assurances that the Company will be successful in accomplishing any of its plans.

The ability of the Company to continue as a going concern is dependent upon its ability to successfully accomplish the plans described in the preceding paragraph and eventually secure other sources of financing and attain profitable operations. The accompanying financial statements do not include any adjustments that might be necessary if the Company is unable to continue as a going concern.

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Oil And Gas Properties
12 Months Ended

Dec. 31, 2016

Extractive Industries [Abstract]

Oil and Gas Properties
NOTE 3 - OIL AND GAS PROPERTIES

On April 3, 2014, the Company signed an election to participate in the first of three wells with Toto Energy, LLC in Cowley County, Kansas. The Company has a 30 percent working interest and a 24.45 percent net royalty interest in the well. As of December 31, 2016, the Company has capitalized $213,000 of cash payments made to commence operations development of the well.

On May 10, 2014, the Company signed an election to participate in the second of three wells with Toto Energy, LLC in Cowley County, Kansas. The Company has a 30 percent working interest and a 24.45 percent net royalty interest in the well. As of December 31, 2016, the Company has capitalized $189,000 of cash payments made to commence operations development of the well.

On July 23, 2016, the Company received $58,684 from the operator of two of its oil and gas leases. The payment received represented a partial refund of the Company’s previous $404,837 in payments made to the operator pursuant to the terms of an Authorization for Expenditures (“AFE”) Agreement. The Company’s original payments under the AFE were capitalized to oil and gas properties in 2014. All capitalized costs pursuant to the AFE were fully impaired during the year ended December 31, 2015. As the capitalized costs had been previously impaired, the $58,684 was recorded as a gain on property settlement for the period ended December 31, 2016.

Oil and gas properties are stated at cost. As of December 31, 2016, and December 31, 2015, oil and gas properties, net consisted of the following:

December 31, 2016 December 31, 2015

Unproved properties $ 470,377 $ 470,377

Impairment of oil and gas leases (470,377 ) (470,377 )

Oil and gas properties, net $ — $ —

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Convertible Notes Payable
12 Months Ended

Dec. 31, 2016

Debt Disclosure [Abstract]

Convertible Notes Payable
NOTE 4 - CONVERTIBLE NOTES PAYABLE

On January 3, 2014, the Company received $600,000 in connection with a convertible note financing commitment, the terms of which call for the Company to receive three tranches of $200,000 each on a callable convertible note wherein the Company borrows the sum at five percent interest for one year and the investor can elect to continue to receive the interest on the note or have the Company issue the investor shares of common stock of the Company at $0.50 per share to retire the debt. The notes came due on December 12, 2014, and as of December 31, 2016 the notes were in default. At December 31, 2016 accrued interest on the notes totaled $89,616.

The Company analyzed the convertible debts under ASC 470-20 and determined that a beneficial conversion feature existed at execution. The intrinsic value of the beneficial conversion feature was determined to be $400,000 and was recorded as additional paid-in capital with an offset to debt discounts. During the years ended December 31, 2016 and 2015, $-0- and $3,288 of the debt discount was amortized to interest expense, respectively, leaving an ending debt discount balance of $-0- at December 31, 2016 and 2015.

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Dec. 31, 2016

Debt Disclosure [Abstract]

Notes Payable
NOTE 5 - NOTES PAYABLE

On May 6, 2015 the Company borrowed $5,000 from an unrelated third-party entity. Pursuant to the terms of the note, the principal accrued interest at a rate of five percent per annum, was unsecured, and came due on May 6, 2016. During the 2016 calendar year, the Company paid the note in full, inclusive of $305 in accrued interest.

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Notes Payable - Related Party
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Dec. 31, 2016

Notes Payable - Related Party

Notes Payable - Related Party
NOTE 6 - NOTES PAYABLE - RELATED PARTY

On June 11, 2015 the Company borrowed $5,000 from a related-party entity. Pursuant to the terms of the note, the principal accrues interest at a rate of five percent per annum, is unsecured, and is due in full on June 11, 2016. Subsequent to the initial borrowing the Company borrowed an additional $57,500 from the same lender under the same terms. On July 25, 2016 the Company paid $40,000 against the outstanding principal of the notes. Accrued interest totaling $1,340 was forgiven at the time of payment, and recorded as additional paid-in capital. At December 31, 2016 the total outstanding principal balance due to the lender was $22,500, and aggregate accrued interest on the notes totaled $465.

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Asset Retirement Obligations
12 Months Ended

Dec. 31, 2016

Asset Retirement Obligation Disclosure [Abstract]

Asset Retirement Obligations
NOTE 7 - ASSET RETIREMENT OBLIGATIONS

The total future asset retirement obligation is estimated by management based on the Company’s net working interests in all wells and facilities, estimated costs to reclaim and abandon wells and facilities and the estimated timing of the costs to be incurred in future periods. At December 31, 2016 and 2015, the Company estimated the undiscounted cash flows related to asset retirement obligation to total approximately $105,000. The actual costs to settle the obligation are expected to occur in approximately 25 years. Through December 31, 2016, the Company established an asset retirement obligation of $9,860 for the wells acquired by the Company, which was capitalized to the value of the oil and gas properties. The fair value of the liability at December 31, 2016 and 2015 is estimated to be $12,323 and $11,534, respectively, using a risk free rate of 9.31 percent and inflation rates between 3.87 and 4.81 percent. Total accretion expense on the asset retirement obligation was $789 and $715 for the years ended December 31, 2016 and 2015, respectively.

Changes to the asset retirement obligation for the years ended December 31, 2016 and 2015 were as follows:

December 31, 2016 December 31, 2015

Balance, beginning of period $ 11,534 $ 10,819

Liabilities incurred — —

Accretion expense 789 715

Balance, end of period $ 12,323 $ 11,534

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Stockholders' Deficit
12 Months Ended

Dec. 31, 2016

Equity [Abstract]

Stockholders' Deficit
NOTE 8 - STOCKHOLDERS’ DEFICIT

The Company has 1,000,000 preferred shares authorized at a par value of $0.001 and 74,000,000 common shares authorized at par value of $0.001. As of December 31, 2016, the Company has 42,013 shares of preferred stock and 42,728,159 shares of common stock issued and outstanding.

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Related-Party Transactions
12 Months Ended

Dec. 31, 2016

Related-party Transactions

Related-Party Transactions
NOTE 9 - RELATED-PARTY TRANSACTIONS

At December 31, 2016 and 2015 the Company was owed its directors an aggregate of $33,000 and $16,000, respectively, in accrued director fees.

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Income Taxes
12 Months Ended

Dec. 31, 2016

Income Tax Disclosure [Abstract]

Income Taxes
NOTE 10 - INCOME TAXES

No provision has been made in the financial statements for income taxes because the Company has accumulated losses from operations since inception. Any deferred tax benefit arising from the operating loss carried forward is offset entirely by a valuation allowance since it is currently not likely that the Company will be significantly profitable in the near future to take advantage of the losses. The provision for income taxes consists of the following:

For the Years Ended

December 31,

2016 2015

Current taxes $ (29,550 ) $ (173,192 )

Impairment of oil and gas properties — 137,645

Valuation allowance 29,550 35,547

Total provision for income taxes $ — $ —

The income tax provision differs from the amount of income tax determined by applying the U.S. federal and state income tax rates of 34% to pretax income from continuing operations for the years ended December 31, 2016 and 2015 due to the following:

December 31,

2016 2015

Loss carry forwards (expire through 2035) $ 1,636,324 $ 1,568,832

Total gross deferred tax asset 698,751 718,676

Valuation allowance (698,751 ) (718,676 )

Net deferred taxes $ — $ —

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Commitments And Contingencies
12 Months Ended

Dec. 31, 2016

Commitments And Contingencies

Commitments and Contingencies
NOTE 11 - COMMITMENTS AND CONTINGENCIES

During the year ended December 31, 2015 the Company became party to a legal action brought about by an unrelated third-party individual, wherein the plaintiff alleges the Company “participated and/or conspired in a scheme to disseminate spam emails” which were misleading in order to encourage individuals to purchase shares of the Company’s common stock at an artificial and/or inflated stock price.

On October 10, 2016, the Company reached a settlement agreement whereby the Company agreed to pay $11,000 in exchange for a general release of all claims against the Company. As of December 31, 2016, the case is considered fully resolved and closed.

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Subsequent Events
12 Months Ended

Dec. 31, 2016

Subsequent Events [Abstract]

Subsequent Events
NOTE 12 - SUBSEQUENT EVENTS

Subsequent to December 31, 2016, the Company cancelled 5,623,097 shares of common stock.

In accordance with ASC 855-10, Company management reviewed all material events through the date of this report and there are no additional material subsequent events to report.

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Supplemental Information To Financial Statements (Unaudited)
12 Months Ended

Dec. 31, 2016

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Supplemental Information To Financial Statements (Unaudited)
SUPPLEMENTAL INFORMATION TO

FINANCIAL STATEMENTS (Unaudited)

Oil and Gas Producing Activities

In January 2010, the Financial Accounting Standards Board (FASB) issued FASB Accounting Standards Update (ASU) No. 2010-03, "Oil and Gas Reserve Estimations and Disclosures" (ASU No. 2010-03). This update aligns the current oil and gas reserve estimation and disclosure requirements of the Extractive Industries - Oil and Gas topic of the FASB Accounting Standards Codification (ASC Topic 932) with the changes required by the final rule of the Securities and Exchange Commission (the “SEC”), "Modernization of Oil and Gas Reporting." ASU No. 2010-03 must be applied prospectively as a change in accounting principle that is inseparable from a change in accounting estimate and is effective for entities with annual reporting periods ending on or after December 31, 2009.

Oil and Gas Reserves Users of this information should be aware that the process of estimating quantities of "proved," "proved developed," "proved undeveloped" and "probable" crude oil, natural gas liquids and natural gas reserves is complex, requiring significant subjective decisions in the evaluation of all available geological, engineering and economic data for each reservoir. The data for a given reservoir may also change substantially over time as a result of numerous factors including, but not limited to, additional development activity, evolving production history and continual reassessment of the viability of production under varying economic conditions. Consequently, material revisions (upward or downward) to existing reserve estimates may occur from time to time. Although reasonable effort is made to ensure that reserve estimates reported represent the most accurate assessments possible, the significance of the subjective decisions required and variances in available data for various reservoirs make these estimates generally less precise than other estimates presented in connection with financial statement disclosures. See ITEM 1A. Risk Factors.

Proved reserves represent estimated quantities of crude oil, natural gas liquids and natural gas that geoscience and engineering data can estimate, with reasonable certainty, to be economically producible from a given day forward from known reservoirs under economic conditions, operating methods and government regulation before the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation.

Proved developed reserves are proved reserves expected to be recovered under operating methods being utilized at the time the estimates were made, through wells and equipment in place or if the cost of any required equipment is relatively minor compared to the cost of a new well.

Proved undeveloped reserves are reserves that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required. Reserves on undrilled acreage are limited to those directly offsetting development spacing areas that are reasonably certain of production when drilled, unless evidence using reliable technology exists that establishes reasonable certainty of economic producibility at greater distances. Undrilled locations can be classified as having undeveloped reserves only if a development plan has been adopted indicating that they are scheduled to be drilled within five years, unless the specific circumstances justify a longer time. Estimates for proved undeveloped reserves are not attributed to any acreage for which an application of fluid injection or other improved recovery technique is contemplated, unless such techniques have been proved effective by actual projects in the same reservoir or an analogous reservoir, or by other evidence using reliable technology establishing reasonable certainty.

Probable undeveloped reserves are those additional reserves that are less certain to be recovered than proved reserves but which, together with proved reserves, are as likely as not to be recovered. Probable reserves may be assigned to areas of a reservoir adjacent to proved reserves where data control or interpretations of available data are less certain, even if the interpreted reservoir continuity of structure or productivity does not meet the reasonable certainty criterion. Probable reserves may be assigned to areas that are structurally higher than the proved area if these areas are in communication with the proved reservoir.

No major acquisition or sale of oil and gas properties or other favorable or adverse event subsequent to December 31, 2016 is believed to have caused a material change in the estimates of proved developed or proved undeveloped or probable undeveloped reserves as of that date.



NET PROVED RESERVE SUMMARY

The following table sets forth the Company's net proved reserves, including proved developed and proved undeveloped reserves, at December 31, 2016 and 2015, as pursuant to reserve reports prepared by the Company’s independent, certified petroleum engineer.



December 31, 2016 December 31, 2015

Net Proved Developed Reserves:

 Crude oil (Bbls) — —

 Natural gas (Mcf) — —

 Oil equivalents (Boa) — —

Net Proved Undeveloped Reserves:

 Crude oil (Bbls) — —

 Natural gas (Mcf) — —

 Oil equivalents (Boe) — —

Net Proved Developed and Undeveloped Reserves:

 Crude oil (Bbls) — —

 Natural gas (Mcf) — —

 Oil equivalents (Boe) — —

Capitalized Costs Relating to Oil and Gas Producing Activities The following table sets forth the capitalized costs relating to the Company’s crude oil and natural gas producing activities at December 31, 2016 and 2015:

At December 31, 2016 At December 31, 2015

Proved leasehold costs $ — $ —

Costs of wells and development 910,855 910,855

Capitalized asset retirement costs 9,860 9,860

Total cost of oil and gas properties 920,715 920,715

Accumulated depreciation, depletion, and impairment (920,715 ) (920,715 )

Net Capitalized Costs $ — $ —

Costs Incurred in Oil and Gas Property Acquisition, Exploration and Development Activities The following table sets forth the costs incurred in the Company’s oil and gas property acquisition, exploration and development activities for the ended December 31, 2016 and 2015:

For the Year Ended December 31, 2016 For the Year Ended December 31, 2015

Acquisition of properties:

 Proved $ — $ —

 Exploration costs — —

 Development costs — —

Net Capitalized Costs $ — $ —

Results of Operations for Oil and Gas Producing Activities The following table sets forth the results of operations for oil and gas producing activities for the year ended December 31, 2016 and 2015:

For the Year Ended December 31, 2016 For the Year Ended December 31, 2015

Crude oil and gas revenues $ — $ 15,008

Production costs (4,079 ) (679 )

Depreciation, depletion and accretion (789 ) (715 )

Results of operations for producing activities, excluding corporate overhead $ (4,868 ) $ 13,614

Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves The following information has been developed utilizing procedures prescribed by ASC Topic 932 and is based on crude oil and natural gas reserves and production volumes estimated by the Company’s independent petroleum consultants. The estimates were based on a $43.92/BO crude oil price. The following information may be useful for certain comparison purposes, but should not be solely relied upon in evaluating the Company or its performance. Further, information contained in the following table should not be considered as representative of realistic assessments of future cash flows, nor should the Standardized Measure of Discounted Future Net Cash Flows be viewed as representative of the current value of the Company.

The future cash flows presented below are based on sales prices, cost rates and statutory income tax rates in existence as of the date of the projections. It is expected that material revisions to some estimates of crude oil and natural gas reserves may occur in the future, development and production of the reserves may occur in periods other than those assumed, and actual prices realized and costs incurred may vary significantly from those used.

Future production and development costs were computed by estimating those expenditures expected to occur in developing and producing the proved oil and natural gas reserves at the end of the year, based on year-end costs. Actual future cash inflows may vary considerably, and the standardized measure does not necessarily represent the fair value of the Company’s oil and natural gas reserves.

Management does not rely upon the following information in making investment and operating decisions. Such decisions are based upon a wide range of factors, including estimates of probable and possible reserves as well as proved reserves, and varying price and cost assumptions considered more representative of a range of possible economic conditions that may be anticipated.

The following table sets forth the standardized measure of discounted future net cash flows from projected production of the Company’s oil and gas reserves as of December 31, 2016 and 2015:



December 31, 2016 December 31, 2015

Future cash inflows $ — $ —

Future production and development costs — —

Future income tax and insurance expense — —

Future net cash inflows — —

10% annual discount for estimated timing of cash flows — —

Standardized measure of discounted future net cash flows $ — $ —

Changes in Standardized Measure of Discounted Future Net Cash Flows The following table sets forth the changes in the standardized measure of discounted future net cash flows for the year ended December 31, 2016 and 2015:

December 31, 2016 December 31, 2015

Beginning of period $ — $ —

 Revenues less production and other costs — —

 Changes in price, net of production costs — —

 Development costs incurred — —

 Net changes in future development costs — —

 Purchases of reserves in place — —

 Accretion of discount — —

 Net change in income taxes — —

 Timing differences and other — —

End of period $ — $ —

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Significant Accounting Policies (Policies)
12 Months Ended

Dec. 31, 2016

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Business Activity
Business Activity

Tiger Oil and Energy, Inc., formerly UTeC, Inc., is a Nevada corporation organized on November 8, 1993 as a “For Profit” corporation for the purpose of engaging in any lawful activity. On January 10, 2007, the Company purchased 100% of the shares of UTeC Corporation, Inc. In 2007, the Company licensed technology covering the use of cold plasma oxidizer technology for the destruction of solid and liquid hazardous chemicals and biologicals. During 2007 and 2008, the Company worked to validate the technology and prepare a business plan for its commercialization.

In April 2009, the Company divested its commercial explosives development, analysis, testing and manufacturing business to eliminate the need to inject new capital into the Company to support this business, and concentrate on raising the funds necessary to commercialize its hazardous waste destruction business. At this time, the Company re-entered the development stage.

Prior to the divestiture, the Company’s business was to offer state of the art testing and analysis to clients worldwide. The Company operated a chemical research and development laboratory near Riverton, Kansas, which specialized in commercial explosives development and analysis. The Company also operated a destructive test facility near Hallowell, Kansas, which specialized in determining the detonating characteristics of commercial explosives.

On October 1, 2009 the Company entered into an agreement to purchase 100% of the outstanding shares of C2R Energy Commodities, Inc., a Nevada corporation, in exchange for 4,050,000 shares of the Company’s restricted common stock. The Company entered into this agreement due primarily to the fact that C2R owned certain intellectual property that the Company wished to acquire.

On October 29, 2010, the Company acquired all of the membership interest in Jett Rink Oil, LLC (“Jett Rink”) in exchange for 10,000,000 shares of the Company’s Common Stock. Jett Rink is involved in the business relating to the exploration, development and production of oil and gas in the United States. At the closing of the Exchange Agreement, Jett Rink became a wholly-owned subsidiary of the Company and the Company acquired the business and operations of Jett Rink.

Basis of Presentation
Basis of Presentation

The accompanying audited consolidated financial statements and related notes include the activity of the Company and its two wholly-owned subsidiaries, C2R Energy Commodities, Inc. and Jett Rink Oil, LLC and have been prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”) and with the rules and regulations of the United States Securities and Exchange Commission (“SEC”) to Form 10-K. All inter-company balances and transactions have been eliminated.

Reclassification
Reclassification

Certain amounts in the prior period financial statements have been reclassified to conform to the current period presentation. These reclassifications had no effect on reported losses.

Consolidation
Consolidation

The accompanying consolidated financial statements included all of the accounts of the Company and its wholly-owned subsidiaries, C2R, Inc., a Nevada Corporation, and Jett Rink Oil, LLC, a Kansas Limited Liability Company. All intercompany transactions have been eliminated.

Accounting Method
Accounting Method

The Company’s financial statements are prepared using the accrual method of accounting. The Company has elected a December 31 year-end.

Use of Estimates
Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

Cash and Cash Equivalents
Cash and Cash Equivalents

For purposes of the Statement of Cash Flows, the Company considers all highly liquid instruments purchased with a maturity of three months or less to be cash equivalents to the extent the funds are not being held for investment purposes. The Company at times may maintain a cash balance in excess of insured limits.

Property, Plant and Equipment
Property, Plant and Equipment

Property and equipment are stated at cost. Major additions and improvements are capitalized in the month following the month in which the assets or improvement are deemed to be placed in service. Maintenance and repairs are expensed as incurred. Upon disposition, the net book value is eliminated from the accounts, with the resultant gain or loss reflected in operations. Depreciation expense is computed on a straight-line basis over the estimate useful lives of the assets as follows:

Building and leasehold improvements 10-25 years

Machinery and equipment 5 years

Furniture and fixtures 3-7 years

The Company periodically assesses the recoverability of property, plant and equipment and evaluates such assets for impairment whenever events or changes in circumstances indicate that the net carrying amount of an asset may not be recoverable. Asset impairment is determined to exist if estimated future cash flows, undiscounted and without interest charges, are less than the net carrying amount.

Impairment of Long-Lived Assets
Impairment of Long-Lived Assets

The Company follows the provisions of ASC 360 for its long-lived assets. The Company’s long-lived assets, which include test equipment and purchased intellectual property rights, are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable.

The Company assesses the recoverability of its long-lived assets by comparing the projected undiscounted net cash flows associated with the related long-lived asset or group of long-lived assets over their remaining estimated useful lives against their respective carrying amounts. Impairment, if any, is based on the excess of the carrying amount over the fair value of those assets. Fair value is generally determined using the asset’s expected future discounted cash flows or market value, if readily determinable. If long-lived assets are determined to be recoverable, but the newly determined remaining estimated useful lives are shorter than originally estimated, the net book values of the long-lived assets are depreciated over the newly determined remaining estimated useful lives.

The Company recognized impairment expense totaling $-0- and $404,837 for the years ended December 31, 2016 and 2015, respectively.

Fair Value of Financial Instruments
Fair Value of Financial Instruments

The fair value of a financial instrument is the amount that could be received upon the sale of an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Financial assets are marked to bid prices and financial liabilities are marked to offer prices. Fair value measurements do not include transaction costs. A fair value hierarchy is used to prioritize the quality and reliability of the information used to determine fair values. Categorization within the fair value hierarchy is based on the lowest level of input that is significant to the fair value measurement. The fair value hierarchy is defined into the following three categories:

Level 1: Quoted market prices in active markets for identical assets or liabilities

Level 2: Observable market-based inputs or inputs that are corroborated by market data

Level 3: Unobservable inputs that are not corroborated by market data

Stock-Based Compensation
Stock-based Compensation

The Company adopted ASC 718 effective January 1, 2006 using the modified prospective method. Under this transition method, stock compensation expense includes compensation expense for all stock-based compensation awards granted on or after January 1, 2006, based on the grant-date fair value estimated in accordance with the provisions of ASC 718.

Provision for Taxes
Provision for Taxes

The Company applies ASC 740, which requires the asset and liability method of accounting for income taxes. This method requires that the current or deferred tax consequences of all events recognized in the financial statements be measured by applying the provisions of enacted tax laws to determine the amount of taxes payable or refundable currently or in future years. Deferred tax assets are reviewed for recoverability and the Company records a valuation allowance to reduce its deferred tax assets when it is more likely than not that all or some portion of the deferred tax assets will not be recovered.

The Company adopted ASC 740, at the beginning of fiscal year 2008. This interpretation requires recognition and measurement of uncertain tax positions using a “more-likely-than-not” approach, requiring the recognition and measurement of uncertain tax positions. The adoption of ASC 740 had no material impact on the Company’s financial statements.

Basic and Diluted Loss Per Share
Basic and Diluted Loss per Share

Basic and diluted loss per share is calculated by dividing the Company’s net loss applicable to common shareholders by the weighted average number of common shares during the period. Diluted earnings per share is calculated by dividing the Company’s net income available to common shareholders by the diluted weighted average number of shares outstanding during the year. The diluted weighted average number of shares outstanding is the basic weighted number of shares adjusted for any potentially dilutive debt or equity. The Company had 1,200,000 potential dilutive shares as of December 31, 2016 that were excluded as their effect was anti-dilutive.

Reporting Segments
Reporting Segments

ASC 280 establishes standards for the way that public enterprises report information about operating segments in annual financial statements and requires reporting of selected information about operating segments in interim financial statements regarding products and services, geographic areas and major customers. ASC 280 defines operating segments as components of an enterprise about which separate financial information is available that is evaluated regularly by the chief operating decision maker in deciding how to allocate resources and in assessing performances. Currently, ASC 280 has no effect on the Company’s consolidated financial statements as substantially all of the Company’s operations are conducted in one industry segment.

Oil and Gas Properties
Oil and Gas Properties

The Company uses the full cost method of accounting for oil and natural gas properties. Under this method, all acquisition, exploration and development costs, including certain payroll, asset retirement costs, other internal costs, and interest incurred for the purpose of finding oil and natural gas reserves, are capitalized. Internal costs that are capitalized are directly attributable to acquisition, exploration and development activities and do not include costs related to production, general corporate overhead or similar activities. Costs associated with production and general corporate activities are expensed in the period incurred. Proceeds from the sale of oil and natural gas properties are applied to reduce the capitalized costs of oil and natural gas properties unless the sale would significantly alter the relationship between capitalized costs and proved reserves, in which case a gain or loss is recognized.

Capitalized costs associated with impaired properties and capitalized costs related to properties having proved reserves, plus the estimated future development costs, and asset retirement costs under Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic 410 “Asset Retirement and Environmental Obligations” (FASB ASC 410), are amortized using the unit-of-production method based on proved reserves. Capitalized costs of oil and natural gas properties, net of accumulated amortization and deferred income taxes, are limited to the total of estimated future net cash flows from proved oil and natural gas reserves, discounted at ten percent, plus the cost of unevaluated properties. Under certain specific conditions, companies could elect to use subsequent prices for determining the estimated future net cash flows. The use of subsequent pricing is no longer allowed. There are many factors, including global events that may influence the production, processing, marketing and price of oil and natural gas. A reduction in the valuation of oil and natural gas properties resulting from declining prices or production could adversely impact depletion rates and capitalized cost limitations. Capitalized costs associated with properties that have not been evaluated through drilling or seismic analysis, including exploration wells in progress at December 31, 2016, are excluded from the unit-of-production amortization. Exclusions are adjusted annually based on drilling results and interpretative analysis.

Sales of oil and natural gas properties are accounted for as adjustments to the net full cost pool with no gain or loss recognized, unless the adjustment would significantly alter the relationship between capitalized costs and proved reserves. If it is determined that the relationship is significantly altered, the corresponding gain or loss will be recognized in the statements of operations.



Costs of oil and gas properties are depleted using the unit-of-production method. For the years ended December 31, 2016 and 2015, the Company recognized $-0- of depletion expense related to oil and gas production during the period.

Ceiling Test
Ceiling Test

In applying the full cost method, the Company performs an impairment test (ceiling test) at each reporting date, whereby the carrying value of property and equipment is compared to the value of its proved reserves discounted at a ten percent interest rate of future net revenues, based on current economic and operating conditions, plus the cost of properties not being amortized, plus the lower of cost or fair market value of unproved properties included in costs being amortized, less the income tax effects related to book and tax basis differences of the properties. During the years ended December 31, 2016 and 2015, the Company had recorded $-0- and $404,837, respectively, of impairment expense in connection with the full cost ceiling test calculation.

Asset Retirement Obligation
Asset Retirement Obligation

The Company follows ASC 410, Asset Retirement and Environmental Obligations which requires entities to record the fair value of a liability for asset retirement obligations (“ARO”) and recorded a corresponding increase in the carrying amount of the related long-lived asset. The asset retirement obligation primarily relates to the abandonment of oil and gas properties. The present value of the estimated asset retirement cost is capitalized as part of the carrying amount of oil and gas properties and is depleted over the useful life of the asset. The settlement date fair value is discounted at our credit adjusted risk-free rate in determining the abandonment liability. The abandonment liability is accreted with the passage of time to its expected settlement fair value. Revisions to such estimates are recorded as adjustments to ARO are charged to operations in the period in which they become known. At the time the abandonment cost is incurred, the Company is required to recognize a gain or loss if the actual costs do not equal the estimated costs included in ARO.

The ARO is based upon numerous estimates and assumptions, including future abandonment costs, future recoverable quantities of oil and gas, future inflation rates, and the credit adjusted risk free interest rate.

Recent Accounting Pronouncements
Recent Accounting Pronouncements

Management has considered all recent accounting pronouncements issued since the last audit of its consolidated financial statements. The Company’s management believes that these recent pronouncements will not have a material effect on the Company’s consolidated financial statements.

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Summary Of Significant Accounting Policies (Tables)
12 Months Ended

Dec. 31, 2016

Summary Of Significant Accounting Policies Tables

Schedule of Estimated Useful Lives of the Assets
Depreciation expense is computed on a straight-line basis over the estimate useful lives of the assets as follows:

Building and leasehold improvements 10-25 years

Machinery and equipment 5 years

Furniture and fixtures 3-7 years

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Oil And Gas Properties (Tables)
12 Months Ended

Dec. 31, 2016

Extractive Industries [Abstract]

Schedule of Oil and Gas Properties
Oil and gas properties are stated at cost. As of December 31, 2016, and December 31, 2015, oil and gas properties, net consisted of the following:

December 31, 2016 December 31, 2015

Unproved properties $ 470,377 $ 470,377

Impairment of oil and gas leases (470,377 ) (470,377 )

Oil and gas properties, net $ — $ —

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Asset Retirement Obligations (Tables)
12 Months Ended

Dec. 31, 2016

Asset Retirement Obligation Disclosure [Abstract]

Schedule of Asset Retirement Obligations
Changes to the asset retirement obligation for the years ended December 31, 2016 and 2015 were as follows:

December 31, 2016 December 31, 2015

Balance, beginning of period $ 11,534 $ 10,819

Liabilities incurred — —

Accretion expense 789 715

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Income Taxes (Tables)
12 Months Ended

Dec. 31, 2016

Income Taxes Tables

Schedule of Provision for Income Taxes
The provision for income taxes consists of the following:

For the Years Ended

December 31,

2016 2015

Current taxes $ (29,550 ) $ (173,192 )

Impairment of oil and gas properties — 137,645

Valuation allowance 29,550 35,547

Total provision for income taxes $ — $ —

Schedule of Deferred Tax Assets
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December 31,

2016 2015

Loss carry forwards (expire through 2035) $ 1,636,324 $ 1,568,832

Total gross deferred tax asset 698,751 718,676

Valuation allowance (698,751 ) (718,676 )

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Supplemental Information To Financial Statements (Unaudited) (Tables)
12 Months Ended

Dec. 31, 2016

Supplemental Information To Financial Statements Tables

Summary of Net Proved Reserves
The following table sets forth the Company's net proved reserves, including proved developed and proved undeveloped reserves, at December 31, 2016 and 2015, as pursuant to reserve reports prepared by the Company’s independent, certified petroleum engineer.



December 31, 2016 December 31, 2015

Net Proved Developed Reserves:

 Crude oil (Bbls) — —

 Natural gas (Mcf) — —

 Oil equivalents (Boa) — —

Net Proved Undeveloped Reserves:

 Crude oil (Bbls) — —

 Natural gas (Mcf) — —

 Oil equivalents (Boe) — —

Net Proved Developed and Undeveloped Reserves:

 Crude oil (Bbls) — —

 Natural gas (Mcf) — —

 Oil equivalents (Boe) — —

Schedule of Capitalized Costs Relating to Oil and Gas Producing Activities
The following table sets forth the capitalized costs relating to the Company’s crude oil and natural gas producing activities at December 31, 2016 and 2015:

At December 31, 2016 At December 31, 2015

Proved leasehold costs $ — $ —

Costs of wells and development 910,855 910,855

Capitalized asset retirement costs 9,860 9,860

Total cost of oil and gas properties 920,715 920,715

Accumulated depreciation, depletion, and impairment (920,715 ) (920,715 )

Net Capitalized Costs $ — $ —

Schedule of Costs Incurred in Oil and Gas Property Acquisition, Exploration and Development Activities
The following table sets forth the costs incurred in the Company’s oil and gas property acquisition, exploration and development activities for the ended December 31, 2016 and 2015:

For the Year Ended December 31, 2016 For the Year Ended December 31, 2015

Acquisition of properties:

 Proved $ — $ —

 Exploration costs — —

 Development costs — —

Net Capitalized Costs $ — $ —

Schedule of Results of Operations for Oil and Gas Producing Activities
The following table sets forth the results of operations for oil and gas producing activities for the year ended December 31, 2016 and 2015:

For the Year Ended December 31, 2016 For the Year Ended December 31, 2015

Crude oil and gas revenues $ — $ 15,008

Production costs (4,079 ) (679 )

Depreciation, depletion and accretion (789 ) (715 )

Results of operations for producing activities, excluding corporate overhead $ (4,868 ) $ 13,614

Schedule of Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves
The following table sets forth the standardized measure of discounted future net cash flows from projected production of the Company’s oil and gas reserves as of December 31, 2016 and 2015:



December 31, 2016 December 31, 2015

Future cash inflows $ — $ —

Future production and development costs — —

Future income tax and insurance expense — —

Future net cash inflows — —

10% annual discount for estimated timing of cash flows — —

Standardized measure of discounted future net cash flows $ — $ —

Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows
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December 31, 2016 December 31, 2015

Beginning of period $ — $ —

 Revenues less production and other costs — —

 Changes in price, net of production costs — —

 Development costs incurred — —

 Net changes in future development costs — —

 Purchases of reserves in place — —

 Accretion of discount — —

 Net change in income taxes — —

 Timing differences and other — —

End of period $ — $ —

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Related-Party Transactions (Narrative) (Details) - USD ($)

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Dec. 31, 2015

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shares

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X

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Number of shares of common stock subject to repurchase or cancellation determined by relating the portion of time within a reporting period that these shares have been outstanding to the total time in that period. Common stock subject to repurchase are outstanding common shares that are contingently returnable (that is, subject to recall).
+ References
Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 260
-SubTopic 10
-Section 45
-Paragraph 13
-URI http://asc.fasb.org/extlink&oid=64863997&loc=d3e2646-109256
+ Details

Name: us-gaap_WeightedAverageNumberOfSharesCommonStockSubjectToRepurchaseOrCancellation

Namespace Prefix: us-gaap_

Data Type: xbrli:sharesItemType

Balance Type: na

Period Type: duration

X

- Details

Name: us-gaap_SubsequentEventTypeAxis=us-gaap_SubsequentEventMember

Namespace Prefix:

Data Type: na

Balance Type:

Period Type:

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1.	I have reviewed this annual report of Tiger Oil and Energy, Inc..

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

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

4.	The Registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(3)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f) for the Registrant and have:

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

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

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

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

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

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

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

Document and Entity Information - USD ($)	12 Months Ended
Document and Entity Information - USD ($)	Dec. 31, 2016	Apr. 11, 2017	Jun. 30, 2016
Document And Entity Information
Entity Registrant Name	Tiger Oil & Energy, Inc.
Entity Central Index Key	0001386018
Document Type	10-K
Document Period End Date	Dec. 31, 2016
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Is Entity a Well-known Seasoned Issuer?	No
Is Entity a Voluntary Filer?	No
Is Entity's Reporting Status Current?	Yes
Entity Filer Category	Smaller Reporting Company
Entity Public Float			$ 0
Entity Common Stock, Shares Outstanding		37,105,062
Document Fiscal Period Focus	FY
Document Fiscal Year Focus	2016

Consolidated Balance Sheets - USD ($)	Dec. 31, 2016	Dec. 31, 2015
CURRENT ASSETS
Cash and cash equivalents	$ 272	$ 15,047
Prepaid expenses and deposits	200	200
Total Current Assets	472	15,247
OTHER ASSETS
Oil and gas properties, net (full cost method)
TOTAL ASSETS	472	15,247
CURRENT LIABILITIES
Accounts payable and accrued expenses	114,380	82,978
Accounts payable - related party	33,000	16,000
Notes payable		5,200
Notes payable - related party	61,500	35,000
Convertible notes payable	600,000	600,000
Total Current Liabilities	808,880	739,178
LONG-TERM LIABILITIES
Asset retirement obligation	12,323	11,534
Total Long-Term Liabilities	12,323	11,534
TOTAL LIABILITIES	821,203	750,712
STOCKHOLDERS' DEFICIT
Preferred stock - 1,000,000 shares authorized, $0.001 par value; 42,013 issued and outstanding	42	42
Common stock - 74,000,000 shares authorized, $0.001 par value; 42,728,159 issued and outstanding	42,728	42,728
Additional paid-in capital	4,676,821	4,675,176
Accumulated deficit	(5,540,322)	(5,453,411)
Total Stockholders' Deficit	(820,731)	(735,465)
TOTAL LIABILITIES AND STOCKHOLDERS' DEFICIT	$ 472	$ 15,247

Consolidated Balance Sheets (Parenthetical) - $ / shares	Dec. 31, 2016	Dec. 31, 2015
Statement of Financial Position [Abstract]
Preferred stock, shares authorized	1,000,000	1,000,000
Preferred stock, par value per share	$ 0.001	$ 0.001
Preferred stock, shares issued	42,013	42,013
Preferred stock, shares outstanding	42,013	42,013
Common stock, shares authorized	74,000,000	74,000,000
Common stock, par value per share	$ 0.001	$ 0.001
Common stock, shares issued	42,728,159	42,728,159
Common stock, shares outstanding	42,728,159	42,728,159

Consolidated Statements Of Operations - USD ($)	12 Months Ended
Consolidated Statements Of Operations - USD ($)	Dec. 31, 2016	Dec. 31, 2015
Income Statement [Abstract]
REVENUES		$ 15,008
OPERATING EXPENSES
Lease operating expense	4,079	679
Accretion expense	789	715
Legal and professional	68,882	46,059
Impairment of oil and gas properties		404,837
General and administrative	36,840	38,365
Total Operating Expenses	110,590	490,655
LOSS FROM OPERATIONS	(110,590)	(475,647)
OTHER INCOME (EXPENSE)
Interest expense	35,005	33,741
Gain on settlement of debt	58,684
Total Other Income (Expense)	23,679	(33,741)
LOSS BEFORE TAXES	(86,911)	(509,388)
Provision for income taxes
NET LOSS	$ (86,911)	$ (509,388)
BASIC AND DILUTED LOSS PER SHARE	$ (0.00)	$ (0.01)
BASIC AND DILUTED WEIGHTED AVERAGE NUMBER OF SHARES OUTSTANDING	42,728,159	42,728,159

Consolidated Statement Of Stockholders' Deficit - USD ($)	Preferred Stock [Member]	Common Stock [Member]	Additional Paid-In Capital [Member]	Accumulated Deficit [Member]	Total
Balance preferred stock, shares at Dec. 31, 2013	42,013				42,013
Balance common stock, shares at Dec. 31, 2013		42,728,159			42,728,159
Balance amount at Dec. 31, 2013	$ 42	$ 42,728	$ 4,275,176	$ (4,457,314)	$ (139,368)
Beneficial conversion on convertible note payable			400,000		400,000
Net loss for the year ended				(486,709)	$ (486,709)
Balance preferred stock, shares at Dec. 31, 2014	42,013				42,013
Balance common stock, shares at Dec. 31, 2014		42,728,159			42,728,159
Balance amount at Dec. 31, 2014	$ 42	$ 42,728	4,675,176	(4,944,023)	$ (226,077)
Beneficial conversion on convertible note payable
Net loss for the year ended				(509,388)	$ (509,388)
Balance preferred stock, shares at Dec. 31, 2015	42,013				42,013
Balance common stock, shares at Dec. 31, 2015		42,728,159			42,728,159
Balance amount at Dec. 31, 2015	$ 42	$ 42,728	4,675,176	(5,453,411)	$ (735,465)
Beneficial conversion on convertible note payable
Settlement of related-party debt			1,645		1,645
Net loss for the year ended				(86,911)	$ (86,911)
Balance preferred stock, shares at Dec. 31, 2016	42,013				42,013
Balance common stock, shares at Dec. 31, 2016		42,728,159			42,728,159
Balance amount at Dec. 31, 2016	$ 42	$ 42,728	$ 4,676,821	$ (5,540,322)	$ (820,731)

Consolidated Statements Of Cash Flows - USD ($)	12 Months Ended
Consolidated Statements Of Cash Flows - USD ($)	Dec. 31, 2016	Dec. 31, 2015
OPERATING ACTIVITIES
Net loss	$ (86,911)	$ (509,388)
Adjustments to Reconcile Net Loss to Net Cash Used by Operating Activities:
Depreciation, amortization and accretion expense	789	715
Gain on property settlement	58,684
Impairment of oil and gas properties		404,837
Amortization of debt discount		3,288
Changes in operating assets and liabilities:
Accounts payable and accrued liabilities	32,847	48,569
Accounts payable - related party	17,000	10,000
Net Cash Used in Operating Activities	(94,959)	(41,979)
INVESTING ACTIVITIES
Proceeds from property settlement	58,684
Net Cash Used in Investing Activities	58,684
FINANCING ACTIVITIES
Proceeds from notes payable - related party	66,500	40,000
Repayments on note payable	5,000
Repayments of notes payable - related party	40,000
Net Cash Provided by Financing Activities	21,500	40,000
NET INCREASE (DECREASE) IN CASH	(14,775)	(1,979)
CASH AT BEGINNING OF PERIOD	15,047	17,026
CASH AT END OF PERIOD	272	15,047
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
CASH PAID FOR: Income taxes
CASH PAID FOR: Interest
NON-CASH FINANCING AND INVESTING ACTIVITIES:
Beneficial conversion on convertible note
Asset retirement obligations

Summary Of Significant Accounting Policies (Details)	12 Months Ended
Summary Of Significant Accounting Policies (Details)	Dec. 31, 2016
Building And Leasehold Improvements [Member] \| Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives of an asset	10 years
Building And Leasehold Improvements [Member] \| Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives of an asset	25 years
Machinery And Equipment [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives of an asset	5 years
Furniture And Fixtures [Member] \| Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives of an asset	3 years
Furniture And Fixtures [Member] \| Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives of an asset	7 years

Oil And Gas Properties (Details) - USD ($)	Dec. 31, 2016	Dec. 31, 2015
Property, Plant and Equipment [Line Items]
Oil and gas properties, net
Oil And Gas Properties - Unproved Properties [Member]
Property, Plant and Equipment [Line Items]
Unproved properties	470,377	470,377
Impairment of oil and gas leases	470,377	470,377
Oil and gas properties, net

Asset Retirement Obligations (Details) - USD ($)	12 Months Ended
Asset Retirement Obligations (Details) - USD ($)	Dec. 31, 2016	Dec. 31, 2015
Asset Retirement Obligations Details
Balance, beginning of period	$ 11,534	$ 10,819
Liabilities incurred
Accretion expense	789	715
Balance, end of period	$ 12,323	$ 11,534

Income Taxes (Schedule Of Provision For Income Taxes) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Income Taxes Schedule Of Provision For Income Taxes Details
Current taxes	$ (29,550)	$ (173,192)
Impairment of oil and gas properties		137,645
Valuation allowance	29,550	35,547
Total provision for income taxes

Income Taxes (Schedule Of Deferred Tax Assets) (Details) - USD ($)	Dec. 31, 2016	Dec. 31, 2015
Income Taxes Schedule Of Deferred Tax Assets Details
Loss carry forwards (expire through 2035)	$ 1,636,324	$ 1,568,832
Total gross deferred tax asset	698,751	718,676
Valuation allowance	698,751	718,676
Net deferred taxes

Supplemental Information To Financial Statements (Unaudited) (Summary Of Net Proved Reserves) (Details)	Dec. 31, 2016 Boe bbl Mcf	Dec. 31, 2015 Boe bbl Mcf
Reserve Quantities [Line Items]
Net Proved Developed Reserves, Oil Equivalents \| Boe
Net Proved Undeveloped Reserves, Oil Equivalents \| Boe
Net Proved Developed and Undeveloped Reserves, Oil Equivalents \| Boe
Crude Oil (Bbls)
Reserve Quantities [Line Items]
Net Proved Developed Reserves: \| bbl
Net Proved Undeveloped Reserves: \| bbl
Net Proved Developed and Undeveloped Reserves: \| bbl
Natural Gas (Mcf)
Reserve Quantities [Line Items]
Net Proved Developed Reserves: \| Mcf
Net Proved Undeveloped Reserves: \| Mcf
Net Proved Developed and Undeveloped Reserves: \| Mcf

Supplemental Information to Financial Statements (Unaudited) (Capitalized Costs Relating To Oil And Gas) (Details) - USD ($)	Dec. 31, 2016	Dec. 31, 2015
Supplemental Information To Financial Statements Capitalized Costs Relating To Oil And Gas Details
Proved leasehold costs
Costs of wells and development	910,855	910,855
Capitalized asset retirement costs	9,860	9,860
Total cost of oil and gas properties	920,715	920,715
Accumulated depreciation, depletion, and impairment	920,715	920,715
Net Capitalized Costs

Supplemental Information To Financial Statements (Unaudited) (Costs Incurred In Property Acquisition) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Acquisition of properties:
Proved
Exploration costs
Development costs
Net Capitalized Costs

Summary Of Significant Accounting Policies (Narrative) (Details) - USD ($)			12 Months Ended
	Oct. 29, 2010	Oct. 01, 2009	Dec. 31, 2016	Dec. 31, 2015	Jan. 10, 2007
Business Acquisition [Line Items]
Antidilutive securities excluded from computation of earnings per share			1,200,000
Depletion expenses			$ 0	$ 0
UTeC Corporation, Inc
Business Acquisition [Line Items]
Acquisition percentage					100.00%
C2R Energy Commodities, Inc [Member] \| Acquisition Agreement [Member]
Business Acquisition [Line Items]
Acquisition percentage		100.00%
C2R Energy Commodities, Inc [Member] \| Acquisition Agreement [Member] \| Restricted Common Stock [Member]
Business Acquisition [Line Items]
Shares issued in consideration for acquisition		4,050,000
Jett Rink Oil, LLC [Member] \| Acquisition Agreement [Member] \| Common Stock [Member]
Business Acquisition [Line Items]
Shares issued in consideration for acquisition	10,000,000

Oil And Gas Properties (Narrative) (Details) - USD ($)		12 Months Ended
Oil And Gas Properties (Narrative) (Details) - USD ($)	Jul. 23, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	May 10, 2014	Apr. 03, 2014
Property, Plant and Equipment [Line Items]
Capitalized cost
Proceeds from property settlement		58,684
Impairment expense			404,837
Gain on property settlement of oil and gas leases		58,684
Participate In First Of Three Wells With Toto Energy, LLC [Member]
Property, Plant and Equipment [Line Items]
Percentage of working interest in the wells						30.00%
Percentage of net royalty interest in the wells						24.45%
Capitalized cost		213,000
Participate In Second Of Three Wells With Toto Energy, LLC [Member]
Property, Plant and Equipment [Line Items]
Percentage of working interest in the wells					30.00%
Percentage of net royalty interest in the wells					24.45%
Capitalized cost		189,000
Authorization For Expenditures ("AFE") Agreement - Two Oil And Gas Leases[Member]
Property, Plant and Equipment [Line Items]
Capitalized cost				$ 404,837
Proceeds from property settlement	$ 58,684
Payments made to capitalize in oil and gas properties				$ 404,837
Impairment expense			$ 404,837
Gain on property settlement of oil and gas leases		$ 58,684

Convertible Notes Payable (Narrative) (Details) - USD ($)		12 Months Ended
	Jan. 03, 2014	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Short-term Debt [Line Items]
Beneficial conversion feature				$ 400,000
Debt discount amortized			3,288
Convertible Notes Payable Dated January 03, 2014 [Member]
Short-term Debt [Line Items]
Convertible notes financing received	$ 600,000
Debt instrument terms	The terms of which call for the Company to receive three tranches of $200,000 each on a callable convertible note wherein the Company borrows the sum at five percent interest for one year.	The notes were in default
Interest rate	5.00%
Debt instrument conversion terms	The investor can elect to continue to receive the interest on the note or have the Company issue the investor shares of common stock of the Company at $0.50 per share to retire the debt.
Debt instrument maturity date	Dec. 12, 2014
Accrued interest		$ 89,616
Beneficial conversion feature	$ 400,000
Debt discount amortized		0	3,288
Debt discount		$ 0	$ 0

Notes Payable (Narrative) (Details) - Notes Payable - Unrelated Third-Party Entity [Member]	May 06, 2015 USD ($)
Short-term Debt [Line Items]
Proceeds from notes payable - unrelated party	$ 5,000
Interest rate	5.00%
Debt instrument terms	It is unsecured, and is due in full.
Debt instrument maturity date	May 06, 2016

Notes Payable - Related Party (Narrative) (Details) - USD ($)						12 Months Ended		19 Months Ended
	Oct. 04, 2016	Jul. 25, 2016	May 02, 2016	Mar. 07, 2016	Jun. 11, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2016	Jul. 25, 2015
Short-term Debt [Line Items]
Proceeds from note payable - related party						$ 66,500	$ 40,000
Repayment of principal outstanding of notes - related party						40,000
Notes payable - related party						61,500	$ 35,000	$ 61,500
Notes Payable Dated June 11, 2015 [Member] \| Related Party Entity [Member]
Short-term Debt [Line Items]
Proceeds from note payable - related party					$ 5,000			57,500
Interest rate					5.00%
Debt instrument terms					It is unsecured, and is due in full.
Debt instrument maturity date					Jun. 11, 2016
Repayment of principal outstanding of notes - related party		$ 40,000
Accrued interest forgiven recorded		1,340
Notes payable - related party						22,500		22,500
Accrued interest						465		465
Assumed Note Payable Dated July 25, 2015 [Member] \| Related Party [Member]
Short-term Debt [Line Items]
Repayment of principal outstanding of notes - related party		5,000
Accrued interest forgiven recorded		$ 305
Unrelated third party entity notes payable assumed by related party									$ 5,000
Notes Payable Dated March 07, 2016 [Member] \| Related Party [Member]
Short-term Debt [Line Items]
Proceeds from note payable - related party	$ 25,000		$ 4,000	$ 10,000
Interest rate				5.00%
Debt instrument terms				It is unsecured, and is due in full.
Debt instrument maturity date				May 06, 2017
Notes payable - related party						39,000		39,000
Accrued interest						$ 848		$ 848

Related-Party Transactions (Narrative) (Details) - USD ($)	Dec. 31, 2016	Dec. 31, 2015
Related Party Transaction [Line Items]
Accrued director fees	$ 33,000	$ 16,000
Directors [Member]
Related Party Transaction [Line Items]
Accrued director fees	$ 33,000	$ 16,000

Income Taxes (Narrative) (Details)	12 Months Ended
Income Taxes (Narrative) (Details)	Dec. 31, 2016 USD ($)
Income Taxes Narrative Details
Effective income tax rate	34.00%
Net operating loss carryforward	$ 1,776,611
Operating loss carryforwards terms	At December 31, 2016, the Company had net operating loss carry forwards of approximately $1,776,611 that may be offset against future taxable income through 2034.

Commitments And Contingencies (Narrative) (Details) - Legal Action By Unrelated Third Party [Member]		12 Months Ended
	Oct. 10, 2016	Dec. 31, 2015
Loss Contingencies [Line Items]
Name of plaintiff		Unrelated third-party individual
Name of defendant		The Company
Plaintiff allegation		The plaintiff alleges the Company “participated and/or conspired in a scheme to disseminate spam emails” which were misleading in order to encourage individuals to purchase shares of the Company’s common stock at an artificial and/or inflated stock price.
Settlement agreement date	October 10, 2016
Settlement agreement terms	On October 10, 2016, the Company reached a settlement agreement whereby the Company agreed to pay $11,000 in exchange for a general release of all claims against the Company. As of December 31, 2016, the case is considered fully resolved and closed.

Subsequent Events (Narrative Details)	3 Months Ended
Subsequent Events (Narrative Details)	Apr. 13, 2017 shares
Subsequent Event [Member]
Cancellation of common stock	5,623,097