UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

 

FORM 10-Q

 

x QUARTERLY REPORT UNDER SECTION 13 OR 15 (D) OF THE SECURITIES EXCHANGE ACT OF 1934 

 

FOR THE QUARTERLY PERIOD ENDED MARCH 31, 2019

 

OR

 

¨ TRANSITION REPORT UNDER SECTION 13 OR 15 (D) OF THE SECURITIES EXCHANGE ACT OF 1934 

 

For the transition period from _______ to _______.

 

Commission file number: 000-29219

 

VIKING ENERGY GROUP, INC.

(Formerly Viking Investments Group, Inc.)

(Exact name of registrant as specified in its charter)

 

Nevada

 

98-0199508

(State or other jurisdiction of incorporation or organization)

(IRS Employer Identification No.)

 

15915 Katy Freeway, Suite 450

Houston, TX 77094

(Address of principal executive offices)

 

(281) 404 4387

(Registrant’s telephone number, including area code)

 

____________________________________________________________

(Former name, former address and former fiscal year, if changed since last report)

 

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

 

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

 

Large Accelerated Filer

¨

Accelerated Filer

¨

Non-Accelerated Filer

¨

Smaller Reporting Company

x

 

 

Emerging Growth Company

¨

 

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨

 

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

 

APPLICABLE ONLY TO CORPORATE ISSUERS 

 

As of May 6, 2019, the registrant had 91,187,081 shares of common stock outstanding.

 

 
 
 
 

 

VIKING ENERGY GROUP, INC.

 

Part I – Financial Information

 
 

Item 1

Financial Statements

3

 

Consolidated Balance Sheets as of March 31, 2019 (unaudited) and December 31, 2018

 

3

 

Consolidated Statements of Operations for the three months ended March 31, 2019 and 2018 (unaudited)

 

4

 

Consolidated Statements of Cash Flows for the three months ended March 31, 2019 and 2018 (unaudited)

 

5

 

Consolidated Statements of Changes in Stockholders’ Equity for the three months ended March 31, 2019 and 2018 (unaudited)

 

6

 

Notes to Consolidated Financial Statements (unaudited)

 

7

 

Item 2

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

 

22

 

Item 3

Quantitative and Qualitative Disclosures about Market Risk

 

28

 

Item 4

Controls and Procedures

 

28

Part II – Other Information

 

Item 1

Legal Proceedings

 

29

 

Item 2

Unregistered Sales of Equity Securities and Use of Proceeds

 

29

 

Item 3

Defaults Upon Senior Securities

 

29

 

Item 4

Mine Safety Disclosures

 

29

 

Item 5

Other Information

 

29

 

Item 6

Exhibits

 

30

 

 
2
 
 

 

PART I—FINANCIAL INFORMATION

 

ITEM 1. FINANCIAL STATEMENTS

 

VIKING ENERGY GROUP, INC.
Consolidated Balance Sheets

 

 

 

March 31,

 

 

December 31,

 

 

 

2019

 

 

2018

 

 

 

(unaudited)

 

 

 

ASSETS

 

 

 

 

 

 

Current assets:

 

 

 

 

 

 

Cash

 

$ 1,011,726

 

 

$ 4,009,892

 

Restricted cash

 

 

3,233,324

 

 

 

-

 

Accounts receivable – oil and gas - net

 

 

3,039,848

 

 

 

258,300

 

Prepaid expenses

 

 

142,054

 

 

 

124,443

 

Total current assets

 

 

7,426,952

 

 

 

4,392,635

 

 

 

 

 

 

 

 

 

 

Oil and gas properties, full cost method

 

 

 

 

 

 

 

 

Proved developed producing oil and gas properties, net

 

 

79,709,969

 

 

 

81,331,986

 

Proved undeveloped and non-producing oil and gas properties, net

 

 

50,252,128

 

 

 

50,492,906

 

Total oil and gas properties, net

 

 

129,962,097

 

 

 

131,824,892

 

 

 

 

 

 

 

 

 

 

Fixed assets, net

 

 

594,023

 

 

 

200,243

 

Derivative asset

 

 

-

 

 

 

681,776

 

Other assets

 

 

110,194

 

 

 

110,194

 

TOTAL ASSETS

 

$ 138,093,266

 

 

$ 137,209,740

 

 

 

 

 

 

 

 

 

 

LIABILITIES AND STOCKHOLDERS’ DEFICIT

 

 

 

 

 

 

 

 

Current liabilities:

 

 

 

 

 

 

 

 

Accounts payable

 

$ 2,979,179

 

 

$ 2,549,280

 

Accrued expenses and other current liabilities

 

 

1,932,326

 

 

 

1,014,661

 

Undistributed revenues and royalties

 

 

1,132,653

 

 

 

1,207,605

 

Derivative liability

 

 

11,595,525

 

 

 

2,531,718

 

Amount due to directors

 

 

395,555

 

 

 

395,555

 

Current portion of long-term debt – net of debt discount

 

 

37,436,624

 

 

 

11,805,582

 

Total current liabilities

 

 

55,471,862

 

 

 

19,504,401

 

Long term debt - net of current portion and debt discount

 

 

68,449,202

 

 

 

92,076,857

 

Operating lease liability

 

 

353,073

 

 

 

-

 

Asset retirement obligation

 

 

4,496,011

 

 

 

4,413,465

 

TOTAL LIABILITIES

 

 

128,770,148

 

 

 

115,994,723

 

 

 

 

 

 

 

 

 

 

Commitments and contingencies (Note 8)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

STOCKHOLDERS’ EQUITY

 

 

 

 

 

 

 

 

Preferred stock, $0.001 par value, 5,000,000 shares authorized, 28,092 shares issued and outstanding as of March 31, 2019 and December 31, 2018

 

 

28

 

 

 

28

 

Common stock, $0.001 par value, 500,000,000 shares authorized,

 

 

 

 

 

 

 

 

91,187,081 and 90,989,025 shares issued and outstanding as of March 31, 2019 and December 31, 2018 respectively.

 

 

91,187

 

 

 

90,989

 

Additional paid-in capital

 

 

32,055,297

 

 

 

32,015,913

 

Accumulated deficit

 

 

(22,823,394 )

 

 

(10,891,913 )

TOTAL STOCKHOLDERS’ EQUITY

 

 

9,323,118

 

 

 

21,215,017

 

TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY

 

$ 138,093,266

 

 

$ 137,209,740

 

 

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

 

 
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VIKING ENERGY GROUP, INC.

Consolidated Statements of Operations (Unaudited)

 

 

 

Three months ended

 

 

 

March 31,

 

 

 

2019

 

 

2018

 

 

 

 

 

 

 

 

Revenue

 

 

 

 

 

 

Oil and gas sales

 

$ 9,346,592

 

 

$ 2,161,947

 

 

 

 

 

 

 

 

 

 

Operating expenses

 

 

 

 

 

 

 

 

Lease operating costs

 

 

2,599,394

 

 

 

1,008,268

 

General and administrative

 

 

1,033,345

 

 

 

900,525

 

Stock based compensation

 

 

39,582

 

 

 

173,487

 

Accretion - ARO

 

 

82,546

 

 

 

48,431

 

Depreciation, depletion and amortization

 

 

2,370,688

 

 

 

489,686

 

Total operating expenses

 

 

6,125,555

 

 

 

2,620,397

 

 

 

 

 

 

 

 

 

 

Income (loss) from operations

 

 

3,221,037

 

 

 

(458,450 )

 

 

 

 

 

 

 

 

 

Other income (expense)

 

 

 

 

 

 

 

 

Interest expense

 

 

(3,131,393 )

 

 

(361,203 )

Amortization of debt discount

 

 

(2,278,959 )

 

 

(708,107 )

Change in fair value of derivatives

 

 

(9,745,583 )

 

 

(354,953 )

Gain on ARO settlement

 

 

-

 

 

 

58,041

 

Interest income

 

 

3,417

 

 

 

-

 

Total other income (expense)

 

 

(15,152,518 )

 

 

(1,366,222 )

 

 

 

 

 

 

 

 

 

Net loss before income taxes

 

 

(11,931,481 )

 

 

(1,824,672 )

Income tax benefit (expense)

 

 

-

 

 

 

271,789

 

 

 

 

 

 

 

 

 

 

Net loss

 

$ (11,931,481

)

 

$ (1,552,883 )

Earnings (loss) per common share

 

 

 

 

 

 

 

 

Basic

 

$ (0.13 )

 

$ (0.02 )

Weighted average number of common shares outstanding

 

 

 

 

 

 

 

 

Basic

 

 

91,103,394

 

 

 

74,306,169

 

 

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

 

 
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VIKING ENERGY GROUP, INC.

Consolidated Statements of Cash Flows (Unaudited)

  

 

 

Three Months Ended

 

 

 

March 31,

 

 

 

2019

 

 

2018

 

 

 

 

 

 

 

 

Cash flows from operating activities:

 

 

 

 

 

 

Net loss

 

$ (11,931,481 )

 

$ (1,552,883 )

Adjustments to reconcile net loss to cash provided (used) in operating activities:

 

 

 

 

 

 

 

 

Change in fair value of derivative liability

 

 

9,745,583

 

 

 

354,953

 

Stock based compensation

 

 

39,582

 

 

 

173,487

 

Depreciation, depletion and amortization

 

 

2,370,688

 

 

 

489,686

 

Amortization of operational right-of-use assets

 

 

1,286

 

 

 

-

 

Gain on ARO settlement

 

 

-

 

 

 

(58,041 )

Accretion – Asset retirement obligation

 

 

82,546

 

 

 

48,431

 

Amortization of debt discount

 

 

2,278,959

 

 

 

708,107

 

Changes in operating assets and liabilities

 

 

 

 

 

 

 

 

Accounts receivable

 

 

(2,781,548 )

 

 

(158,621 )

Prepaid expenses and other assets

 

 

(17,611 )

 

 

(75,903 )

Other receivable

 

 

-

 

 

 

60,228

 

Accounts payable

 

 

(263,807 )

 

 

(2,100,581 )

Accrued expenses and other current liabilities

 

 

917,665

 

 

 

267,054

 

Deferred tax liability

 

 

-

 

 

 

(271,789 )

Undistributed revenues and royalties

 

 

(74,952 )

 

 

(62,070 )

Amounts due to directors

 

 

-

 

 

 

25,191

 

Net cash provided by (used) in operating activities

 

 

366,910

 

 

 

(2,152,751 )

 

 

 

 

 

 

 

 

 

Cash flows from investing activities:

 

 

 

 

 

 

 

 

Investment in and acquisition of oil and gas properties

 

 

(493,126 )

 

 

(963,709 )

Acquisition of fixed assets

 

 

-

 

 

 

(130,000 )

Proceeds from sale of oil and gas interests

 

 

-

 

 

 

1,144,953

 

Net cash used in investing activities

 

 

(493,126 )

 

 

(51,244 )

 

 

 

 

 

 

 

 

 

Cash flows from financing activities:

 

 

 

 

 

 

 

 

Proceeds from amount due to directors

 

 

 

 

 

 

583,000

 

Repayment of amount due to directors

 

 

-

 

 

 

(938,771 )

Proceeds from long term debt

 

 

-

 

 

 

3,992,143

 

Short term advance

 

 

693,706

 

 

 

-

 

Repayment of long-term debt

 

 

(332,332 )

 

 

(5,322,981 )

Net cash provided by financing activities

 

 

361,374

 

 

 

(1,686,609 )

 

 

 

 

 

 

 

 

 

Net increase (decrease) in cash

 

 

235,158

 

 

 

(3,788,116 )

Cash and Restricted Cash, beginning of period

 

 

4,009,892

 

 

 

5,735,259

 

 

 

 

 

 

 

 

 

 

Cash and Restricted Cash, end of period

 

$ 4,245,050

 

 

$ 1,947,143

 

Supplemental Cash Flow Information:

Cash paid for:

 

 

 

 

 

 

 

 

Interest

 

$ 2,239,731

 

 

$ 231,822

 

Income taxes

 

$ -

 

 

$ -

 

 

 

 

 

 

 

 

 

 

Supplemental disclosure of Non-Cash Investing and Financing Activities:

 

 

 

 

 

 

 

 

Recognition of asset retirement obligation

 

$ -

 

 

$ 231,053

 

Recognition of right-of-use asset and lease liability

 

$ 367,365

 

 

$ -

 

Amortization of right-of-use asset and lease liability

 

$ 14,292

 

 

$ -

 

Purchase of transportation equipment through direct financing

 

$ 56,760

 

 

$ -

 

Issuance of shares as discount on debt

 

$ -

 

 

$ 615,185

 

 

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

 

 
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VIKING ENERGY GROUP, INC.

Consolidated Statements of Changes in Stockholders’ Equity (Unaudited)

  

For the three months ended March 31, 2019

 

 

 

 Common Stock

 

 

 Preferred Stock

 

 

 Additional

 Paid-in

 

 

Prepaid   Equity-Based

 

 

Retained

Earnings (Accumulated

 

 

 Total

 Stockholders'

 

 

 

 Number

 

 

 Amount

 

 

 Number

 

 

 Amount

 

 

 Capital

 

 

 Compensation

 

 

  Deficit)

 

 

 Equity

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 Balances at December 31, 2018

 

 

90,989,025

 

 

$ 90,989

 

 

 

28,092

 

 

$ 28

 

 

$ 32,015,913

 

 

$ -

 

 

$ (10,891,913 )

 

$ 21,215,017.0

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Shares issued for services

 

 

198,056

 

 

 

198

 

 

 

 

 

 

 

 

 

 

 

39,384

 

 

 

 

 

 

 

 

 

 

 

39,582

 

Net loss for the three months ended March 31, 2019

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(11,931,481 )

 

$ (11,931,481 )

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Balances at March 31, 2019

 

 

91,187,081

 

 

$ 91,187

 

 

 

28,092

 

 

$ 28

 

 

$ 32,055,297

 

 

$ -

 

 

$ (22,823,394 )

 

$ 9,323,118

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

For the three months ended March 31, 2018

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Common Stock

 

 

Preferred Stock

 

 

 

Additional

Paid-in

 

 

Prepaid

Equity-Based

 

 

Retained
Earnings (Accumulated

 

 

Total

Stockholders'

 

 

 

Number

 

 

Amount

 

 

Number

 

 

Amount

 

 

Capital

 

 

Compensation

 

 

Deficit)

 

 

Equity

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Balances at December 31, 2017

 

 

72,347,990

 

 

$ 72,348

 

 

 

28,092

 

 

$ 28

 

 

$ 19,029,892

 

 

$ (11,827 )

 

$ 3,417,872

 

 

 

22,508,313

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Accounting principle change relative to certain derivative liabilities - Note 2.

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

807,762

 

 

 

807,762

 

Shares issued for consulting services

 

 

668,500

 

 

 

669

 

 

 

 

 

 

 

 

 

 

 

116,991

 

 

 

 

 

 

 

 

 

 

 

117,660

 

Shares issued as prepaid equity-based compensation

 

 

250,000

 

 

 

250

 

 

 

 

 

 

 

 

 

 

 

54,750

 

 

 

(55,000 )

 

 

 

 

 

 

-

 

Shares issued as debt discount

 

 

4,110,000

 

 

 

4,110

 

 

 

 

 

 

 

 

 

 

 

611,075

 

 

 

 

 

 

 

 

 

 

 

615,185

 

Amortization of prepaid equity-based compensation

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

55,827

 

 

 

 

 

 

 

55,827

 

Net loss for the three months ended March 31, 2018

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(1,552,883 )

 

 

(1,552,883 )

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Balances at March 31, 2018

 

 

77,376,490

 

 

$ 77,377

 

 

 

28,092

 

 

$ 28

 

 

$ 19,812,708

 

 

$ (11,000 )

 

$ 2,672,751

 

 

$ 22,551,864

 

 

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

 

 
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VIKING ENERGY GROUP, INC.

Notes to Consolidated Financial Statements

(Unaudited)

 

Note 1 Nature of Business and Going Concern 

 

Viking Energy Group, Inc. (“Viking” or the “Company”) is incorporated under the laws of the State of Nevada. The Company's business plan is to engage in the acquisition, exploration, development and production of oil and natural gas properties, both individually and through collaborative partnerships with other companies in this field of endeavor. Since 2014 the Company has had the following related activities:

 

 

· In November 2014, the Company entered into its first contract relative to oil and gas activities involving jointly controlled assets and related liabilities by purchasing an undivided 50% interest in the Joffre project located in Alberta, Canada. Effective September 30, 2018, the Company negotiated a sale and settlement of this Canadian joint venture interest and a resolution of all intercompany balances associated with it, for proceeds to the Company of $232,545. An asset retirement obligation of $466,031 offset by the net asset retirement cost of $293,296 associated with this investment generated a gain from disposal of these assets of $405,280.

 

 

 

 

· In February 2016, the Company closed on the acquisition of working interests in four leases with access to the mineral rights (oil and gas) concerning approximately 281 acres of property in Miami and Franklin Counties in eastern Kansas.

 

 

 

 

· In October 2016, the Company, through its subsidiary Mid-Con Petroleum, LLC (“Mid-Con Petroleum”), completed an acquisition whereby the Company (i) increased its working interest in three existing oil and gas leases in Miami and Franklin Counties in Eastern Kansas, and (ii) acquired a working interest in four new oil and gas leases in the same region, comprising approximately 660 acres of property.

 

 

 

 

· On September 11, 2017, the Company through its subsidiary Mid-Con Drilling, LLC (“Mid-Con Drilling”), completed an acquisition of a 90% working interest in four new oil and gas leases in Anderson County in Eastern Kansas, comprising approximately 980 acres of property.

 

 

 

 

· On October 2, 2017, the Company, through Mid-Con Drilling, closed on an acquisition, effective October 1, 2017, of a 100% working interest in six new oil and gas leases in Miami and Franklin Counties in Eastern Kansas.

 

 

 

 

· On October 4, 2017, the Company, through Mid-Con Drilling, closed on an acquisition of an 80% working interest in six new oil and gas leases in Riley, Geary and Wabaunsee Counties in Kansas.

 

 

 

 

· On December 22, 2017, the Company completed an acquisition of 100% of the membership interests of Petrodome Energy, LLC, a privately-owned company, with working interests in multiple oil and gas fields across Texas, Louisiana and Mississippi, comprising approximately 11,700 acres.

 

 

 

 

· On December 29, 2017, the Company through its subsidiary Mid-Con Development, LLC (“Mid-Con Development”), completed an acquisition of working interests in approximately 41 oil leases in Ellis and Rooks Counties in Kansas, comprising several thousand acres.

 

 

 

 

· On January 12, 2018, the Company, through Mid­Con Drilling, completed an acquisition of a 100% working interest in seven new oil and gas leases in Woodson and Allen Counties in Eastern Kansas.

 

 

 

 

· Effective February 1, 2018, the Company, through Mid-Con Drilling, closed on the acquisition of a working interest in a lease with access to the mineral rights (oil and gas) concerning approximately 80 acres of property in Douglas County in eastern Kansas.

 

 

 

 

· On December 28, 2018, the Company, through its subsidiary Ichor Energy, LLC (“Ichor Energy”) completed an acquisition (the “Ichor Energy Acquisition”) of working interests in certain oil and gas leases in Texas (primarily in Orange and Jefferson Counties) and Louisiana (primarily in Calcasiue Parish), which include 58 producing wells and 31 salt water disposal wells. The properties produce hydrocarbons from known reservoirs/sands in the on-shore Gulf Coast region, with an average well depth in excess of 10,600 feet.
 
 

 
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These accompanying consolidated financial statements have been prepared on a going concern basis, which contemplates the realization of assets and the satisfaction of liabilities in the normal course of business. However, the Company had a net loss of $11,931,481, and $1,552,883 for the three months ended March 31, 2019 and 2018, respectively. Furthermore, as of March 31, 2019, the Company has a working capital deficiency in excess of $48,000,000. The largest components of current liabilities creating this deficiency are (a) notes payable with a face value aggregating approximately $15,000,000 due in August of 2019 and (b) a promissory note payable to the seller of the certain oil and gas interests purchased on December 28, 2018 in the amount of $23,777,948 with all principal and accrued interest due on the earlier of (i) the date the Company or one of its affiliates completes an acquisition with one or more of the Sellers for a purchase price equal to or greater than $50,000,000 or (ii) January 31, 2020.

 

Management has evaluated these conditions and has developed a plan which, in part, address these obligations as follows:

 

 

·

The terms of the $15 million notes due in August 2019 allow for 50% of the principal to be converted into shares of the Company’s common stock at $0.20 per share, and contain a provision whereby the Company has the right to extend the Maturity Date for one additional year to August of 2020. Consideration for the one-year extension is payment of the accrued interest, an increase in the interest rate to 12% for the extension period and the issuance of a warrant to purchase an additional 115,000 common shares per $100,000 of outstanding principal of each note on a pro rata basis. The net effect allows the Company to pay $1,500,000 in accrued interest and delay the payment of $15,000,000 in principal for one year.

 

·

The acquisition of oil and gas assets in Texas and Louisiana (the Ichor Energy Acquisition) at the end of 2018 is believed to provide cash flow sufficient to not only satisfy the Company’s debt service associated with this acquisition, but to also fund a $12,000,000 development program to increase this purchased production beyond its current average daily production of 2,300 BOE and provide a quicker principal reduction, resulting in an increased equity position relative to these assets. The acquisition of Petrodome in 2017 and the high level of oil and gas expertise retained by Petrodome at the end of 2017 provided an internal lease operating company to efficiently evaluate development opportunities.

 

·

The Company has a revolving credit facility with CrossFirst Bank, which was approved for $30,000,000. The balance outstanding at March 31, 2019 is approximately $11,500,000. Additional funds could be made available to the Company for projects reviewed and approved by the lender.

 

These conditions raise substantial doubt regarding the Company’s ability to continue as a going concern. The Company’s ability to continue as a going concern is dependent upon its ability to utilize the resources in place to generate future profitable operations, to develop additional acquisition opportunities, and to obtain the necessary financing to meet its obligations and repay its liabilities arising from business operations when they come due. Management believes the Company will be able to continue to develop new opportunities, and will be able to obtain additional funds through debt and / or equity financings to facilitate its development strategy; however, there is no assurance of additional funding being available. These consolidated financial statements do not include any adjustments to the recorded assets or liabilities that might be necessary should the Company have to curtail operations or be unable to continue in existence.

 

 
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Note 2 Summary of Significant Accounting Policies 

 

a) Basis of Presentation 

 

The accompanying unaudited consolidated financial statements of the Company have been prepared in accordance with generally accepted accounting principles in the United States of America (“GAAP”) and the interim reporting rules of the Securities and Exchange Commission (“SEC”) and should be read in conjunction with the audited financial statements and notes thereto contained in Viking’s latest Annual Report filed with the SEC on Form 10-K. In the opinion of management, all adjustments, consisting of normal recurring adjustments (unless otherwise indicated), necessary for a fair presentation of the financial position and the results of operations for the interim periods presented have been reflected herein. The results of operations for interim periods are not necessarily indicative of the results to be expected for the full year.

 

b) Basis of Consolidation

 

The financial statements presented herein reflect the consolidated financial results of the Company and its wholly owned subsidiaries: Viking Oil & Gas (Canada) ULC, a Canadian corporation formed to provide a base of operations for properties in Canada; Mid-Con Petroleum, LLC, Mid-Con Drilling, LLC, and Mid-Con Development, LLC, which were all formed to provide a base of operations for properties in the Central United States; and Petrodome Energy, LLC (and its subsidiaries) and Ichor Energy Holdings, LLC, its subsidiary Ichor Energy, LLC (Ichor Energy”), and Ichor Energy’s subsidiaries, Ichor Energy (TX), LLC, and Ichor Energy (LA), LLC, which provide a base of operations to facilitate property acquisitions in Texas, Louisiana and Mississippi. All significant intercompany transactions and balances have been eliminated.

 

c) Use of Estimates in the Preparation of Financial Statements

 

The preparation of consolidated financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the reported amounts and timing of revenues and expenses, the reported amounts and classification of assets and liabilities, and disclosure of contingent assets and liabilities. Significant areas requiring the use of management estimates relate to impairment of long-lived assets, stock-based compensation, asset retirement obligations, and the determination of expected tax rates for future income tax recoveries.

 

The estimates of proved, probable and possible oil and gas reserves are used as significant inputs in determining the depletion of oil and gas properties and the impairment of proved and unproved oil and gas properties. There are numerous uncertainties inherent in the estimation of quantities of proved, probable and possible reserves and in the projection of future rates of production and the timing of development expenditures. Similarly, evaluations for impairment of proved and unproved oil and gas properties are subject to numerous uncertainties including, among others, estimates of future recoverable reserves and commodity price outlooks. Actual results could differ from the estimates and assumptions utilized.

 

 
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d) Financial Instruments 

 

Accounting Standards Codification, “ASC” Topic 820-10, “Fair Value Measurement” requires disclosure of the fair value of financial instruments held by the Company. ASC Topic 820-10, defines fair value, and establishes a three-level valuation hierarchy for disclosures of fair value measurement that enhances disclosure requirements for fair value measurement. The carrying amounts reported in the consolidated balance sheets for other receivable – related party, long-term investment, accrued expenses and other current liabilities, accounts payable, derivative liabilities, amount due to directors, and convertible notes each qualify as financial instruments and are a reasonable estimate of their fair values because of the short period of time between the origination of such instruments and their expected realization and their current market rate of interest. The three levels of valuation hierarchy are defined as follows:

 

 

·

Level 1: inputs to the valuation methodology are quoted prices (unadjusted) for identical assets or liabilities in active markets.

 

 

·

Level 2: inputs to the valuation methodology include quoted prices for similar assets and liabilities in active markets, and inputs that are observable for the asset or liability, either directly or indirectly, for substantially the full term of the financial instrument.

 

 

·

Level 3: inputs to the valuation methodology are unobservable and significant to the fair value measurement.

 

Assets and liabilities measured at fair value as of March 31, 2019 are classified below based on the three fair value hierarchy described above:

 

Description

 

Quoted Prices in Active Markets for Identical Assets

(Level 1)

 

 

Significant Other Observable Inputs

(Level 2)

 

 

Significant Unobservable Inputs

(Level 3)

 

 

Total Gains
(Losses)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Financial Assets

 

 

 

 

 

 

 

 

 

 

 

 

Commodity Derivative

 

 

-

 

 

 

-

 

 

 

-

 

 

 

-

 

 

 

$ -

 

 

$ -

 

 

$ -

 

 

$ -

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Financial liabilities

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Commodity Derivative

 

 

 

 

 

 

11,595,525

 

 

 

-

 

 

 

(9,745,583 )

 

 

$ -

 

 

$ 11,595,525

 

 

$ -

 

 

$ (9,745,583 )

 

Assets and liabilities measured at fair value as of December 31, 2018, are classified below based on the three-level fair value hierarchy described above:

 

Description

 

Quoted Prices in Active Markets for Identical Assets

(Level 1)

 

 

Significant Other Observable Inputs

(Level 2)

 

 

Significant Unobservable Inputs

(Level 3)

 

 

Total Gains
(Losses)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Financial Assets

 

 

 

 

 

 

 

 

 

 

 

 

Commodity Derivative

 

$ -

 

 

$ 681,776

 

 

$ -

 

 

$ 926,802

 

 

 

$ -

 

 

$ 681,776

 

 

$ -

 

 

$ 926,802

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Financial liabilities

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Commodity Derivative

 

 

-

 

 

 

2,531,718

 

 

 

-

 

 

 

(2,531,718 )

 

 

$ -

 

 

$ 2,531,718

 

 

$ -

 

 

$ (2,531,718 )

 

 
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The Company has entered into certain commodity derivative instruments containing swaps and collars, which are effective in mitigating commodity price risk associated with a portion of its future monthly natural gas and crude oil production and related cash flows. The Company does not designate its commodities derivative instruments as hedges and therefore does not apply hedge accounting. Changes in fair value of derivative instruments subsequent to the initial measurement are recorded as change in fair value on derivative liability, in other income (expense). The estimated fair value amounts of the Company’s commodity derivative instruments have been determined at discrete points in time based on relevant market information which resulted in the Company classifying such derivatives as Level 2. Although the Company’s commodity derivative instruments are valued using public indices, as well as the Black-Sholes model, the instruments themselves are traded with unrelated counterparties and are not openly traded on an exchange.

 

In a commodities swap agreement, the Company trades the fluctuating market prices of oil or natural gas at specific delivery points over a specified period, for fixed prices. As a producer of oil and natural gas, the Company holds these commodity derivatives to protect the operating revenues and cash flows related to a portion of its future natural gas and crude oil sales from the risk of significant declines in commodity prices, which helps reduce exposure to price risk and improves the likelihood of funding its capital budget. If the price of a commodity rises above what the Company has agreed to receive in the swap agreement, the amount that it agreed to pay the counterparty is expected to be offset by the increased amount it received for its production.

 

The Company has also entered into collar agreements related to oil and gas production with established floors and ceilings. Upon settlement, if the current market price of the commodity is below the floor, the Company receives the difference. Conversely, if the current market price of the commodity is above the ceiling at settlement, the Company pays the excess over the ceiling price.

 

Although the Company is exposed to credit risk to the extent of nonperformance by the counterparties to these derivative contracts, the Company does not anticipate such nonperformance and monitors the credit worthiness of its counterparties on an ongoing basis.

 

The derivative assets were $0 and $681,776 as of March 31, 2019 and December 31, 2018, and the derivative liabilities were $11,595,525 and $2,531,718 as of March 31, 2019 and December 31, 2018 respectively. The change in the fair value of the derivative assets and liabilities for the three months ended March 31, 2019 consisted of a decrease of $681,776 associated with existing commodity derivatives and a decrease of $9,063,807 associated with the new commodity derivative related to the acquisition accomplished on December 28, 2018, and a loss recognized in the consolidated statement of operations in the amount of $9,745,583.

 

 
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The table below is a summary of the Company’s commodity derivatives as of March 31, 2019:

 

Natural Gas

 

Period

 

Average MMBTU per Month

 

 

Fixed Price per MMBTU

 

 

 

 

 

 

 

 

 

 

Swap

 

Dec-18 to Dec-22

 

 

118,936

 

 

$ 2.715

 

 

Crude Oil

 

Period

 

Average BBL
per Month

 

 

Price per BBL

 

 

 

 

 

 

 

 

 

 

Swap

 

Dec-18 to Dec- 22

 

 

24,600

 

 

$ 50.85

 

Swap

 

Dec-17 to Dec-19

 

 

1,400

 

 

$ 54.77

 

Swap

 

Jan-20 to Jun-20

 

 

1,400

 

 

$ 52.71

 

Collar

 

Dec-17 to Jun-20

 

 

4,000

 

 

$

55.00 / $72.00

 

Collar

 

Sep-17 to Sep-19

 

 

1,100

 

 

$

47.00 / $54.10

 

 

e) Cash and Cash Equivalents 

 

Cash and cash equivalents include cash in banks and highly liquid investment securities that have original maturities of three months or less. At March 31, 2019, the Company has cash deposits in excess of FDIC insured limits in the amounts of $3,183,623

 

Restricted cash in the amount of $3,233,324 as of March 31, 2019 represents the balance of cash in the Ichor Energy LLC subsidiaries, generated through the operations of those subsidiaries and restricted for operations, debt service and development projects within those subsidiaries.

 

f) Accounts receivable

 

Accounts receivable consist of oil and gas receivables. The Company evaluates these accounts receivable for collectability and, when necessary, records allowances for expected unrecoverable amounts. The Company has recorded an allowance for doubtful accounts of $217,057 at March 31, 2019 and December 31, 2018 respectively. 

 

g) Oil and Gas Properties

 

The Company uses the full cost method of accounting for its investment in oil and natural gas properties. Under this method of accounting, all costs associated with acquisition, exploration and development of oil and gas reserves, including directly related overhead costs, are capitalized. General and administrative costs related to production and general overhead are expensed as incurred.

 

All capitalized costs of oil and gas properties, including the estimated future costs to develop proved reserves, are amortized on the unit of production method using estimates of proved reserves. Disposition of oil and gas properties are accounted for as a reduction of capitalized costs, with no gain or loss recognized unless such adjustment would significantly alter the relationship between capitalized costs and proved reserves of oil and gas, in which case the gain or loss is recognized in operations. Unproved properties and major development projects are not amortized until proved reserves associated with the projects can be determined or until impairment occurs. If the results of an assessment indicate that the properties are impaired, the amount of the impairment is included in loss from operations before income taxes and the adjusted carrying amount of the unproved properties is amortized on the unit-of-production method.

 

 
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Depreciation, depletion and amortization expense utilizing the unit-of-production method for the Company’s oil and gas properties for the three months ended March 31, 2019 and 2018 were as follows:

 

Oil and Gas Properties by Geographical Cost Center

 

 

Three months ended,

 

 

 

March 31,

 

Cost Center

 

2019

 

 

2018

 

 

 

 

 

 

 

 

Canada

 

$ -

 

 

$ 10,738

 

United States

 

 

2,370,688

 

 

 

478,948

 

 

 

 

 

 

 

 

 

 

 

 

$ 2,370,688

 

 

$ 489,686

 

 

h) Limitation on Capitalized Costs

 

Under the full-cost method of accounting, we are required, at the end of each reporting date, to perform a test to determine the limit on the book value of our oil and natural gas properties (the “Ceiling” test). If the capitalized costs of our oil and natural gas properties, net of accumulated amortization and related deferred income taxes, exceed the Ceiling, this excess or impairment is charged to expense. The expense may not be reversed in future periods, even though higher oil and natural gas prices may subsequently increase the Ceiling. The Ceiling is defined as the sum of:

 

(a) the present value, discounted at 10 percent, and assuming continuation of existing economic conditions, of 1) estimated future gross revenues from proved reserves, which is computed using oil and natural gas prices determined as the unweighted arithmetic average of the first-day-of-the-month price for each month within the 12-month hedging arrangements pursuant to SAB 103, less 2) estimated future expenditures (based on current costs) to be incurred in developing and producing the proved reserves, plus

 

(b) the cost of properties not being amortized; plus

 

(c) the lower of cost or estimated fair value of unproven properties included in the costs being amortized, net of

 

(d) the related tax effects related to the difference between the book and tax basis of our oil and natural gas properties.

 

i) Oil and Gas Reserves

 

Reserve engineering is a subjective process that is dependent upon the quality of available data and the interpretation thereof, including evaluations and extrapolations of well flow rates and reservoir pressure. Estimates by different engineers often vary sometimes significantly. In addition, physical factors such as the results of drilling, testing and production subsequent to the date of an estimate, as well as economic factors such as changes in product prices, may justify revision of such estimates. Because proved reserves are required to be estimated using recent prices of the evaluation, estimated reserve quantities can be significantly impacted by changes in product prices.

 

 
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j) Loss per Share

 

Basic net loss per share is computed by dividing the net loss by the weighted-average number of common shares outstanding during the period. Diluted net loss per share is computed by dividing the net loss by the weighted-average number of common shares and, adjusted by any effects of warrants and options outstanding, if dilutive, that may add to the number of common shares during the period. At March 31, 2019 and 2018 there were approximately 92,274,782 and 31,503,126 common stock equivalents respectively, that were anti-dilutive.

 

k) Revenue Recognition 

 

Sales of crude oil, natural gas, and natural gas liquids (NGLs) are included in revenue when production is sold to a customer in fulfillment of performance obligations under the terms of agreed contracts. Performance obligations primarily comprise delivery of oil, gas, or NGLs at a delivery point, as negotiated within each contract. Each barrel of oil, million BTU (MMBtu) of natural gas, or other unit of measure is separately identifiable and represents a distinct performance obligation to which the transaction price is allocated. Performance obligations are satisfied at a point in time once control of the product has been transferred to the customer. The Company considers a variety of facts and circumstances in assessing the point of control transfer, including but not limited to: whether the purchaser can direct the use of the hydrocarbons, the transfer of significant risks and rewards, the Company’s right to payment, and transfer of legal title. In each case, the time between delivery and when payments are due is not significant.

 

The following table disaggregates the Company’s revenue by source for the three months ended March 31, 2019 and 2018:

 

 

 

Three Months Ended
March 31,

 

 

 

2019

 

 

2018

 

 

 

 

 

 

 

 

Oil

 

$ 7,732,163

 

 

$ 2,024,184

 

Natural gas and Natural gas liquids

 

 

1,614,429

 

 

 

137,763

 

 

 

 

 

 

 

 

 

 

 

 

$ 9,346,592

 

 

$ 2,161,947

 

 

l) Income Taxes

 

The Company accounts for income taxes under the asset and liability method, which requires the recognition of deferred tax assets and liabilities for the expected future tax consequences of events that have been included in the consolidated financial statements. Under this method, the Company determines deferred tax assets and liabilities on the basis of the differences between the consolidated financial statements and the tax basis of assets and liabilities by using estimated tax rates for the year in which the differences are expected to reverse.

 

 
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The Company recognizes deferred tax assets and liabilities to the extent that we believe that these assets and/or liabilities are more likely than not to be realized. In making such a determination, we consider all available positive and negative evidence, including future reversals of existing taxable temporary differences, projected future taxable income, tax planning strategies, and results of recent operations. If we determine that the Company would be able to realize our deferred tax assets in the future in excess of their net recorded amount, we would make an adjustment to the deferred tax asset valuation allowance, which would reduce the provision for income taxes.

 

In assessing the realizability of its deferred tax assets, management evaluated whether it is more likely than not that some portion, or all of its deferred tax assets, will be realized. The realization of its deferred tax assets relates directly to the Company’s ability to generate taxable income. The valuation allowance is then adjusted accordingly.

 

The Company has estimated net operating losses in excess of $12,000,000 at March 31, 2019. The potential benefit of these net operating losses has not been recognized in these financial statements because the Company cannot be assured it is more likely than not that it will utilize the net operating losses carried forward in future years. The net operating loss carryforwards will expire between 2027 through 2037.

 

m) Stock-Based Compensation

 

The Company may issue stock options to employees and stock options or warrants to non-employees in non-capital raising transactions for services and for financing costs. The cost of stock options and warrants issued to employees and non-employees is measured on the grant date based on the fair value. The fair value is determined using the Black-Scholes option pricing model. The resulting amount is charged to expense on the straight-line basis over the period in which the Company expects to receive the benefit, which is generally the vesting period.

 

The fair value of stock options and warrants is determined at the date of grant using the Black-Scholes option pricing model. The Black-Scholes option model requires management to make various estimates and assumptions, including expected term, expected volatility, risk-free rate, and dividend yield. The expected term represents the period of time that stock-based compensation awards granted are expected to be outstanding and is estimated based on considerations including the vesting period, contractual term and anticipated employee exercise patterns. Expected volatility is based on the historical volatility of the Company’s stock. The risk-free rate is based on the U.S. Treasury yield curve in relation to the contractual life of stock-based compensation instrument. The dividend yield assumption is based on historical patterns and future expectations for the Company dividends.

 

The following table represents stock warrant activity as of and for the three months ended March 31, 2019:

 

 

 

Number of
Shares

 

 

Weighted

Average

Exercise

Price

 

 

Weighted

Average

Remaining

Contractual Life

 

 

Aggregate

Intrinsic

Value

 

Warrants Outstanding – December 31, 2018

 

 

54,821,690

 

 

 

0.26

 

 

6.0 years

 

 

 

-

 

Granted

 

 

-

 

 

 

-

 

 

 

 

 

 

-

 

Exercised

 

 

-

 

 

 

-

 

 

 

-

 

 

 

-

 

Forfeited/expired/cancelled

 

 

-

 

 

 

 

 

 

 

-

 

 

 

-

 

Warrants Outstanding – March 31, 2019

 

 

54,821,690

 

 

$ 0.26

 

 

4.7 years

 

 

$ -

 

Outstanding Exercisable – December 31, 2018

 

 

54,821,690

 

 

$ 0.26

 

 

6.0 years

 

 

$ -

 

Outstanding Exercisable – March 31, 2019

 

 

54,821,690

 

 

$ 0.26

 

 

4.7 years

 

 

$ -

 

 

 
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n) Impairment of long-lived assets 

 

In accordance with ASC 360, "Accounting for the Impairment or Disposal of Long-Lived Assets", the Company is required to review its long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable through the estimated undiscounted cash flows expected to result from the use and eventual disposition of the assets. Whenever any such impairment exists, an impairment loss will be recognized for the amount by which the carrying value exceeds the fair value.

 

Assets are grouped and evaluated at the lowest level for their identifiable cash flows that are largely independent of the cash flows of other groups of assets. The Company considers historical performance and future estimated results in its evaluation of potential impairment and then compares the carrying amount of the asset to the future estimated cash flows expected to result from the use of the asset. If the carrying amount of the asset exceeds estimated expected undiscounted future cash flows, the Company measures the amount of impairment by comparing the carrying amount of the asset to its fair value. The estimation of fair value is generally determined by using the asset's expected future discounted cash flows or market value. The Company estimates fair value of the assets based on certain assumptions such as budgets, internal projections, and other available information as considered necessary. There is no impairment of long-lived assets during the three months ended March 31, 2019 and 2018.

 

o) Derivative Liability

 

We review the terms of convertible debt issues to determine whether there are embedded derivative instruments, including embedded conversion options, which are required to be bifurcated and accounted for separately as derivative financial instruments. In circumstances where the host instrument contains more than one embedded derivative instrument, including the conversion option, that is required to be bifurcated, the bifurcated derivative instruments are accounted for as a single, compound derivative instrument

 

Bifurcated embedded derivatives are initially recorded at fair value and are then revalued at each reporting date with changes in the fair value reported as non-operating income or expense. When the equity or convertible debt instruments contain embedded derivative instruments that are to be bifurcated and accounted for as liabilities, the total proceeds received are first allocated to the fair value of all the bifurcated derivative instruments. The remaining proceeds, if any, are then allocated to the host instruments themselves, usually resulting in those instruments being recorded at a discount from their face value. The discount from the face value of the convertible debt, together with the stated interest on the instrument, is amortized over the life of the instrument through periodic charges to interest expense. 

 

The Company has evaluated the terms and conditions of its convertible notes. The conversion feature did not meet the definition of “indexed to a company’s own stock” due to the down round protection feature. Therefore, the conversion feature requires bifurcation and liability classification. Additionally, the default put requires bifurcation because it is indexed to risks that are not associated with credit or interest risk. As a result, the compound embedded derivative comprises of (i) the embedded conversion feature and (i) the default put. Rather than bifurcating and recording the compound embedded derivative as a derivative liability, the Company elected to initially and subsequently measure the convertible note in its entirety at fair value, with changes in fair value recognized in earnings. On January 1, 2018, the Company adopted ASU 2017-11, Derivatives and Hedging (Topic 815), and increased beginning retained earnings in the amount of $807,762.

 

p) Accounting for Asset Retirement Obligations

 

Asset retirement obligations (“ARO”) primarily represent the estimated present value of the amount the Company will incur to plug, abandon and remediate its producing properties at the projected end of their productive lives, in accordance with applicable federal, state and local laws. The Company determined its ARO by calculating the present value of estimated cash flows related to the obligation. The retirement obligation is recorded as a liability at its estimated present value as of the obligation’s inception, with an offsetting increase to proved properties.

 

 
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The following table describes the changes in the Company’s asset retirement obligations for the three months ended March 31, 2019: 

 

 

 

Three months
ended

March 31,
2019

 

 

 

 

 

Asset retirement obligation – beginning

 

$ 4,413,465

 

Oil and gas purchases

 

 

-

 

Adjustments through disposals and settlements

 

 

-

 

Accretion expense

 

 

82,546

 

 

 

 

 

 

Asset retirement obligation – ending

 

$ 4,496,011

 

 

q) Undistributed Revenues and Royalties

 

The Company records a liability for cash collected from oil and gas sales that have not been distributed. The amounts get distributed in accordance with the working interests of the respective owners.

 

r) Recent Accounting Pronouncements

 

In February 2016, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update No. 2016-02 “Leases” (ASU 2016-02) and subsequently issued supplemental adoption guidance and clarification (collectively, Topic 842). Topic 842 amends a number of aspects of lease accounting, including requiring lessees to recognize right-of-use assets and lease liabilities for operating leases with a lease term greater than one year. Topic 842 supersedes Topic 840 “Leases.” On January 1, 2019, the Company adopted Topic 842 using the modified retrospective approach. Results for reporting periods beginning after January 1, 2019 are presented under Topic 842, while prior period amounts are not adjusted and continue to be reported in accordance with our historical accounting under Topic 840. We elected the package of practical expedients permitted under the transition guidance within Topic 842, which allowed us to carry forward the historical lease classification, retain the initial direct costs for any leases that existed prior to the adoption of the standard and not reassess whether any contracts entered into prior to the adoption are leases. We also elected to account for lease and non-lease components in our lease agreements as a single lease component in determining lease assets and liabilities. In addition, we elected not to recognize the right-of-use assets and liabilities for leases with lease terms of one year or less. Upon adoption of Topic 842, we recorded $367,365 of right-of-use assets and operating lease liabilities as of January 1, 2019. The adoption did not have a material impact on our Consolidated Statements of Operations or Consolidated Statements of Cash Flows

 

 
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In July 2017, the Financial Accounting Standards Board (“FASB”) issued ASU 2017-11, “Earnings Per Share (Topic 260); Distinguishing Liabilities from Equity (Topic 480); Derivatives and Hedging (Topic 815): (Part 1) Accounting for Certain Financial Instruments with Down Round Features, (Part II) Replacement of the Indefinite Deferral for Mandatorily Redeemable Financial Instruments of Certain Non-public Entities and Certain Mandatorily Redeemable Non-controlling Interests with a Scope Exception” (“ASU 2017-11”). Part I relates to the accounting for certain financial instruments with down round features in Subtopic 815-40, which is considered in determining whether an equity-linked financial instrument qualifies for a scope exception from derivative accounting. Down round features are features of certain equity-linked instruments (or embedded features) that result in the strike price being reduced based on the pricing of future equity offerings. An entity still is required to determine whether instruments would be classified as equity in determining whether they qualify for that scope exception. If they do qualify, freestanding instruments with down round features are no longer classified as liabilities. ASU 2017-11 is effective for annual reporting periods beginning after December 15, 2018, including interim periods within that reporting period. Early adoption is permitted, including in an interim period. We adopted Topic 815 as of January 1, 2018. The effect was to no longer recognize certain freestanding instruments with down round features as a liability, through an increase in beginning retained earnings of $807,762

 

s) Subsequent events

 

The Company has evaluated all subsequent events from March 31, 2019, through the date of filing this report, and determined there are no additional items to disclose other than those described in Note 9.

 

Note 3. Business Acquisition 

 

Proforma unaudited condensed selected financial data for the three months ended March 31, 2018 as though the Ichor Energy Acquisition had taken place at January 1, 2018 are as follows:

 

 

 

Three Months
Ended

March 31,
2018

 

 

 

 

 

Revenues

 

$ 10,740,279

 

 

 

 

 

 

Net Income (excludes unrealized gains / losses) 

 

$ 832,948

 

 

 

 

 

 

Income per share

 

$ 0.32

 

 

 
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Note 4. Oil and Gas Properties 

 

The following table summarizes the Company’s oil and gas activities by classification and geographical cost center for the three months ended March 31, 2019:

 

 

 

December 31,
2018

 

 

Adjustments

 

 

Impairments

 

 

March 31,
2019

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Proved developed producing oil and gas properties

 

 

 

 

 

 

 

 

 

 

 

 

United States cost center

 

$ 81,936,721

 

 

$ 101,474

 

 

$ -

 

 

$ 82,038,195

 

Accumulated depreciation, depletion and amortization

 

 

(604,735 )

 

 

(1,723,491 )

 

 

-

 

 

 

(2,328,226 )
Proved developed producing oil and gas properties, net

 

$ 81,331,986

 

 

$ (1,622,017 )

 

$ -

 

 

$ 79,709,969

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Undeveloped and non-producing oil and gas properties

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

United States cost center

 

$ 51,973,719

 

 

$ 391,652

 

 

$ -

 

 

$ 52,365,371

 

Accumulated depreciation, depletion and amortization

 

 

(1,480,813 )

 

 

(632,430 )

 

 

-

 

 

 

(2,113,243 )
Undeveloped and non-producing oil and gas properties, net

 

$ 50,492,906

 

 

$ (240,778 )

 

$ -

 

 

$ 50,252,128

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Total Oil and Gas Properties, Net

 

$ 131,824,892

 

 

$ (1,862,795 )

 

$ -

 

 

$ 129,962,097

 

 

Note 5. Related Party Transactions

 

The Company’s CEO and Director, James Doris has previously incurred expenses on behalf of, and made advances to the Company in order to provide the Company with funds to carry on its operations. As of March 31, 2019, the total amount due to Mr. Doris for unreimbursed expenses is $6,183, and is included in accounts payable. Additionally, Mr. Doris has made several loans through promissory notes to the Company, all accruing interest at 12%, and payable on demand. As of March 31, 2019, the total amount due to Mr. Doris for these loans is $395,555 Accrued interest of $69,912 is included in accrued expenses and other current liabilities at March 31, 2019.

 

The Company’s CFO, Frank W. Barker, Jr., renders professional services to the Company through FWB Consulting, Inc., an affiliate of Mr. Barker’s. As of March 31, 2019, the total amount due to FWB Consulting, Inc. is $114,468, and is included in accounts payable.

 

Note 6. Capital Stock and Additional Paid-in Capital 

 

(a) Preferred Stock

 

The Company is authorized to issue 5,000,000 shares of Preferred Stock, par value $0.001 per share (the “Preferred Stock”), of which 50,000 have been designated as Series C Preferred Stock (the “Series C Preferred Stock”). Each share of Series C Preferred Stock entitles the holder thereof to 10,000 votes on all matters submitted to the vote of the stockholders of the Company. Each share of Series C Preferred Stock is convertible, at the option of the holder, at any time after the date of issuance of such share, at the office of the Corporation or any transfer agent for such stock, into one share of fully paid and non-assessable common stock (the “Conversion Rate”).

 

(b) Common Stock

 

On November 5, 2018, the Company amended its Articles of Incorporation to increase the number of shares of common stock the Company is authorized to issue from 100,000,000 to 500,000,000.

 

 
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During the three months ended March 31, 2019, the Company issued the shares of its common stock as follows:

 

 

· 198,056 shares of common stock issued for services valued at fair market value on the date of the transaction, totaling $39,582.
 

During the three months ended March 31, 2018, the Company issued the shares of its common stock as follows:

 

 

· 668,500 shares of common stock issued for services valued at fair market value on the date of the transaction, totaling $117,660.

 

 

 

 

· 250,000 shares of common stock issued as prepaid equity-based compensation valued at fair market value at the date of the transaction, totaling $55,000.

 

 

 

 

· 4,110,000 shares of common stock issued as debt discount valued at fair market value on the date of each transaction, totaling $615,185.
 

Note 7. Long Term Debt

 

Long term debt consisted of the following at March 31, 2019 and December 31, 2018:

  

 

 

March 31,
2019

 

 

December 31,

2018

 

 

 

 

 

 

 

 

During June through December of 2018, the Company borrowed $9,459,750 from private lenders, and exchanged $5,514,000 of amounts due lenders from prior borrowings as well as $191,250 in accrued interest, pursuant to a 10% Secured Promissory Note with 50% of the principal convertible into the Company’s common stock at $0.20 per share, all principal and accrued interest payable on the maturity date of August 31, 2019. The balance shown is net of unamortized discount of $3,935,573 at March 31, 2019 and $5,981,012 at December 31, 2018.

 

 

11,214,427

 

 

 

9,168,988

 

 

 

 

 

 

 

 

 

 

On June 13, 2018, the Company borrowed $12,400,000 pursuant to a revolving line of credit facility with a maximum principal amount of $30,000,000 from Crossfirst Bank, bearing interest 1.5% above a base rate equal to the prime rate of interest published by the Wall Street Journal, interest only for June and July of 2018, at which time Principal will be payable at $100,000 monthly through the maturity date of September 30, 2020, at which time all remaining unpaid principal and accrued interest shall be due. The balance shown is net of unamortized discount of $86,405 at March 31, 2019 and $103,421 at December 31, 2018

 

 

11,413,595

 

 

 

11,728,911

 

 

 

 

 

 

 

 

 

 

On December 28, 2018, to facilitate the acquisition of certain oil and gas assets, the Company, through one of its subsidiaries, Ichor Energy LLC, entered into a Term Loan Credit Agreement with various lenders represented by ABC Funding, LLC as administrative agent. The agreement provides for a total loan amount of $63,592,000, bearing interest at a rate per annum equal to the greater of (i) a floating rate of interest equal to 10% plus LIBOR, and (ii) a fixed rate of interest equal to 12%, payable monthly on the last day of each calendar month, commencing January 31, 2019. Principal payments shall be made quarterly at 1.25% of the initial loan amount, commencing on the last business day of the fiscal quarter ending June 30, 2019. Cash generated from the operation of these assets is restricted to lease operating expenses, the payment of debt service on the Term Loan, approximately $12,000,000 of oil and gas development projects approved by the lender, and distributions to the Company of $65,000 per month for general and administrative expenses, and a quarterly tax distribution at the current statutory rates. On a quarterly basis, commencing with the quarter ended June 30, 2019, after appropriate distributions to the Company, any cash in excess of $2,000,000 plus unfunded approved development projects will be swept by the lender as an additional principal payment on the debt. To the extent not previously paid, all loans under the Loan Agreement shall be due and payable on the December 28, 2023 (the Maturity Date). The balance shown is net of unamortized discount of $4,168,904 at March 31, 2019 and $4,385,408 at December 31, 2018.

 

 

59,423,096

 

 

 

59,206,592

 

 

 

 

 

 

 

 

 

 

On December 28, 2018, the Company issued a 10% secured promissory note in the amount of $23,777,948, payable to RPM Investments, secured by 100% of the membership interests of Ichor Energy Holdings, LLC. All accrued interest and unpaid principal are due on January 31, 2020.

 

 

23,777,948

 

 

 

23,777,948

 

 

 

 

 

 

 

 

 

 

On February14, 2019, the Company executed a promissory note payable to CrossFirst Bank in the amount of $56,760 for the purchase of transportation equipment, bearing interest at 7.15%, payable in 60 installments of $1,130, with a maturity date of February 14,2024

 

 

56,760

 

 

 

-

 

 

 

 

 

 

 

 

 

 

 

 

 

105,885,826

 

 

 

103,882,439

 

Less current portion

 

 

(37,436,624 )

 

 

(11,805,582 )

 

 

$ 68,449,202

 

 

$ 92,076,857

 

 

 
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Note 8. Commitments and contingencies 

 

In April 2018, the Company’s subsidiary, Petrodome Energy, LLC entered into a 66-month lease for 4,147 square feet of office space for the Company’s corporate office in Houston, Texas. The annual base rent commenced at $22.00 per square foot, and escalates at $0.50 per foot each year through expiration of the lease term. A right-of-use asset and operating lease liability has been recorded with the adoption of Topic 842, pertaining to this office lease. As this lease does not provide an implicit interest rate, we used a portfolio approach to determine a collateralized incremental borrowing rate of 10% based on the information available at the date of adoption of Topic 842 to determine the lease liability. Operating lease expense is recognized on a straight-line basis over the lease term. Operating lease expense was $24,096 for the three months ended March 31, 2019.

 

From time to time the Company may be a party to litigation involving commercial claims against the Company. Management believes that the ultimate resolution of these matters will not have a material effect on the Company’s financial position or results of operations.

 

The staff (the “Staff”) of the SEC’s Division of Enforcement has notified the Company, that the Staff has made a preliminary determination to recommend that the SEC file an enforcement action against the Company, as well as against its CEO and it CFO, for alleged violations of Section 17(a) of the Securities Act of 1933 and Section 10(b) of the Securities Exchange Act of 1934 and Rule 10b-5 thereunder during the period from early 2014 through late 2016. The Staff’s notice is not a formal allegation or a finding of wrongdoing by the Company, and the Company is in dialogue with the Staff regarding its preliminary determination. The Company believes it has adequate defenses, and intends to vigorously defend any enforcement action that may be initiated by the SEC.

 

Note 9. Subsequent Events

 

On April 5, 2019, the Company borrowed $145,000 from James A. Doris, the Company’s CEO, under a 12% unsecured promissory note payable on demand.

 

On May 1, 2019, the Company’s subsidiary, Mid-Con Development, LLC sold to an independent third party all of its interests in the oil and gas assets Mid-Con Development, LLC owned in Ellis and Rooks Counties, Kansas, consisting of working interests in approximately 41 oil leases comprising several thousand acres. The sale price was $4,100,000, $3,800,000 of which was applied toward the reserve-based loan (“RBL”) previously provided by CrossFirst Bank to Mid-Con and certain of Viking’s other subsidiaries. The principal balance of the RBL was reduced from approximately $11,400,000 to approximately $7,600,000 as a result of the payment. The balance of the sale proceeds was used for transaction costs and working capital purposes.

 

On May 10, 2019, Petrodome Louisiana Pipeline LLC ("Petrodome LA"), a subsidiary of Petrodome Energy, LLC, acquired from Legacy Resources Co., L.P. ("Legacy") a majority working interest in 6 gas wells (including 2 producing gas wells), 1 producing oil well and 1 salt water disposal well in Cameron Parish, Louisiana. The purchase price was $2,800,000, before adjustments, and the effective date of the transaction was March 1, 2019. The purchase price after adjustments, paid by Petrodome LA to Legacy on closing was $2,706,143, all of which was funded via a drawdown against the RBL. The principal balance of the RBL was increased to approximately $10,334,143, including a separate advance of $28,000 covering closing costs. CrossFirst Bank has a first mortgage against the assets acquired by Petrodome LA.

 

 
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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

 

You should read the following discussion and analysis in conjunction with the financial statements and notes thereto appearing elsewhere in this Quarterly Report on Form 10-Q. In preparing the management’s discussion and analysis, the registrant presumes that you have read or have access to the discussion and analysis for the preceding fiscal year.

 

SPECIAL NOTE REGARDING FORWARD-LOOKING STATEMENTS

 

This document includes “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995 or the Reform Act. All statements other than statements of historical fact are “forward-looking statements” for purposes of federal and state securities laws, including, but not limited to, any projections of earning, revenue or other financial items; any statements of the plans, strategies and objectives of management for future operations; any statements concerning proposed new services or developments; any statements regarding future economic conditions of performance; and statements of belief; and any statements of assumptions underlying any of the foregoing. Such forward-looking statements involve known and unknown risks, uncertainties and other factors which may cause the actual results, performance or achievements of the Company to be materially different from any future results, performance or achievements expressed or implied by such forward-looking statements. Such factors include, among others, the following: our ability to raise capital and the terms thereof; ability to gain an adequate player base to generate the expected revenue; competition with established gaming websites; adverse changes in government regulations or polices; and other factors referenced in this Form 10-Q.

 

The use in this Form 10-Q of such words as “believes”, “plans”, “anticipates”, “expects”, “intends”, and similar expressions are intended to identify forward-looking statements, but are not the exclusive means of identifying such statements. These forward-looking statements present the Company’s estimates and assumptions only as of the date of this Report. Except for the Company’s ongoing obligation to disclose material information as required by the federal securities laws, the Company does not intend, and undertakes no obligation, to update any forward-looking statements.

 

Although the Company believes that the expectations reflected in any of the forward-looking statements are reasonable, actual results could differ materially from those projected or assumed or any of the Company’s forward-looking statements. The Company’s future financial condition and results of operations, as well as any forward-looking statements, are subject to change and inherent risks and uncertainties.

 

PLAN OF OPERATIONS

 

Overview

 

The Company's business plan is to engage in the acquisition, exploration, development and production of oil and natural gas properties, both individually and through collaborative partnerships with other companies in this field of endeavor. Viking has relationships with industry experts and formulated an acquisition strategy, with emphasis on acquiring under-valued, producing properties from distressed vendors or those deemed as non-core assets by larger sector participants. The Company does not focus on speculative exploration programs, but rather targets properties with current production and untapped reserves. The Company’s growth strategy includes the following key initiatives:

 

 

· Acquisition of under-valued producing oil and gas assets

 

· Employ enhanced recovery techniques to maximize production

 

· Implement responsible, lower-risk drilling programs on existing assets

 

· Aggressively pursue cost-efficiencies

 

· Opportunistically explore strategic mergers and/or acquisitions

 

· Actively hedge mitigating commodity risk
 

The following overview provides a background for the current strategy being implemented by management.

 

 
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Acquisitions – Canada

 

 

· In November 2014, the Company entered into its first contract relative to oil and gas activities involving jointly controlled assets and related liabilities by purchasing an undivided 50% interest in the Joffre project located in Alberta, Canada. The working interests of this joint venture, were acquired from a Canadian Company that ended up in receivership, and the administration of these assets proved to be inefficient and unprofitable. The investment in these properties, as well as all uncollected receivables associated with it have been either fully impaired or fully reserved. Effective September 30, 2018, the Company negotiated a sale and settlement of this Canadian joint venture interest and a resolution of all intercompany balances associated with it, for proceeds to the Company of $232,545. An asset retirement obligation of $466,031 offset by the net asset retirement cost of $293,296 associated with this investment generated a gain from disposal of these assets of $405,280.
 

Acquisitions – Kansas

 

 

· In February 2016, the Company closed on the acquisition of working interests in four leases with access to the mineral rights (oil and gas) concerning approximately 281 acres of property in Miami and Franklin Counties in eastern Kansas.

 

 

 

 

· In October 2016, the Company, through its subsidiary Mid-Con Petroleum, LLC, completed an acquisition whereby the Company (i) increased its working interest in three existing oil and gas leases in Miami and Franklin Counties in Eastern Kansas, and (ii) acquired a working interest in four new oil and gas leases in the same region, comprising approximately 660 acres of property.

 

 

 

 

· On September 11, 2017, the Company through its subsidiary Mid-Con Drilling, LLC (“Mid-Con Drilling”), completed an acquisition of a 90% working interest in four new oil and gas leases in Anderson County in Eastern Kansas, comprising approximately 980 acres of property.

 

 

 

 

· On October 2, 2017, the Company, through Mid-Con Drilling, closed on an acquisition, effective October 1, 2017, of a 100% working interest in six new oil and gas leases in Miami and Franklin Counties in Eastern Kansas.

 

 

 

 

· On October 4, 2017, the Company, through Mid-Con Drilling, closed on an acquisition of an 80% working interest in six new oil and gas leases in Riley, Geary and Wabaunsee Counties in Kansas.

 

 

 

 

· On December 29, 2017, the Company through its subsidiary Mid-Con Development, LLC, completed an acquisition of working interests in approximately 41 oil leases in Ellis and Rooks Counties in Kansas, comprising several thousand acres.

 

 

 

 

· On January 12, 2018, the Company, through Mid­Con Drilling, completed an acquisition of a 100% working interest in seven new oil and gas leases in Woodson and Allen Counties in Eastern Kansas.

 

 

 

 

· Effective February 1, 2018, the Company, through Mid-Con Drilling, closed on the acquisition of a working interest in a lease with access to the mineral rights (oil and gas) concerning approximately 80 acres of property in Douglas County in eastern Kansas. On May 1, 2019, the Company’s subsidiary, Mid-Con Development, LLC, sold its oil and gas assets in Ellis and Rooks Counties, Kansas.
 

These Kansas properties are operated by third party contractors. The Company’s plans relative to these properties includes the development of the production potential of existing wells and capitalizing on the drilling opportunities that exist within the acreage covered by these working interests. In 2018, the Company began drilling new wells in various Kansas locations.

 

 
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Acquisitions – Texas, Louisiana and Mississippi

 

 

· On December 22, 2017, the Company completed an acquisition of 100% of the membership interests of Petrodome Energy, LLC, a privately-owned company, with working interests in multiple oil and gas fields across Texas, Louisiana and Mississippi, comprising approximately 11,700 acres.
 

As a part of this acquisition, the Company retained an operational office in Houston, Texas that includes several senior level professionals with over 100 years of combined oil and gas experience which provides the Company the capability of operating many of its own wells internally. This expertise has since been utilized to evaluate additional oil and gas acquisitions, evaluate the profitable management of all of the Company’s oil and gas assets, and evaluate and develop new drilling prospects.

 

Acquisitions – Texas and Louisiana

 

 

· On December 28, 2018, the Company, through its newly formed Ichor Energy subsidiaries completed an acquisition (the “Ichor Energy Acquisition”) of working interests in certain oil and gas leases in Texas (primarily in Orange and Jefferson Counties) and Louisiana (primarily in Calcasiue Parish), which include 58 producing wells and 31 salt water disposal wells. The properties produce hydrocarbons from known reservoirs/sands in the on-shore Gulf Coast region, with an average well depth in excess of 10,600 feet, and daily production volumes averaging in excess of 2,300 BOE.
 

This acquisition of these assets is consistent with the location of our Petrodome assets and are effectively managed from our Houston office.

 

Going Concern Qualification

 

These accompanying consolidated financial statements have been prepared on a going concern basis, which contemplates the realization of assets and the satisfaction of liabilities in the normal course of business. However, the Company had a net loss of $11,931,481, and $1,552,883 for the three months ended March 31, 2019 and 2018, respectively. Furthermore, as of March 31, 2019, the Company has a working capital deficiency in excess of $48,000,000. The largest components of current liabilities creating this deficiency are (a) notes payable with a face value aggregating approximately $15,000,000 due in August of 2019 and (b) a promissory note payable to the seller of the certain oil and gas interests purchased on December 28, 2018 in the amount of $23,777,948 with all principal and accrued interest due on the earlier of (i) the date the Company or one of its affiliates completes an acquisition with one or more of the Sellers for a purchase price equal to or greater than $50,000,000 or (ii) January 31, 2020.

 

Management has evaluated these conditions and has developed a plan which, in part, address these obligations as follows:

 

 

·

The terms of the $15 million notes due in August 2019 allow for 50% of the principal to be converted into shares of the Company’s common stock at $0.20 per share, and contain a provision whereby the Company has the right to extend the Maturity Date for one additional year to August of 2020. Consideration for the one-year extension is payment of the accrued interest, an increase in the interest rate to 12% for the extension period and the issuance of a warrant to purchase an additional 115,000 common shares per $100,000 of outstanding principal of each note on a pro rata basis. The net effect allows the Company to pay $1,500,000 in accrued interest and delay the payment of $15,000,000 in principal for one year.

 

·

The acquisition of oil and gas assets in Texas and Louisiana (the Ichor Energy Acquisition) at the end of 2018 is believed to provide cash flow sufficient to not only satisfy the Company’s debt service associated with this acquisition, but to also fund a $12,000,000 development program to increase this purchased production beyond its current average daily production of 2,300 BOE and provide a quicker principal reduction, resulting in an increased equity position relative to these assets. The acquisition of Petrodome in 2017 and the high level of oil and gas expertise retained by Petrodome at the end of 2017 provided an internal lease operating company to efficiently evaluate development opportunities.

 

·

The Company has a revolving credit facility with CrossFirst Bank, which was approved for $30,000,000. The balance outstanding at March 31, 2019 is approximately $11,500,000. Additional funds could be made available to the Company for projects reviewed and approved by the lender.

 

 
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These conditions raise substantial doubt regarding the Company’s ability to continue as a going concern. The Company’s ability to continue as a going concern is dependent upon its ability to utilize the resources in place to generate future profitable operations, to develop additional acquisition opportunities, and to obtain the necessary financing to meet its obligations and repay its liabilities arising from business operations when they come due. Management believes the Company will be able to continue to develop new opportunities, and will be able to obtain additional funds through debt and / or equity financings to facilitate its development strategy; however, there is no assurance of additional funding being available. These consolidated financial statements do not include any adjustments to the recorded assets or liabilities that might be necessary should the Company have to curtail operations or be unable to continue in existence.

 

RESULTS OF CONTINUING OPERATIONS

 

The following discussion of the financial condition and results of operation of the Company for the three months ended March 31, 2019 and 2018, should be read in conjunction with the audited consolidated financial statements and the notes thereto in the Company’s Annual Report on Form 10-K for the year ended December 31, 2018, filed with the SEC on April 1, 2019.

 

Liquidity and Capital Resources

 

As of March 31, 2019, and December 31, 2018, the Company had $4,245,050 and $4,009,892 in cash holdings, respectively.

 

Three months ended March 31, 2019, compared to the three months ended March 31, 2018

 

Revenue

 

The Company had gross revenues of $9,346,592 for the three months ended March 31, 2019, as compared to $2,161,947 for the three months ended March 31, 2018, reflecting an increase in excess of 330% or $7,184,645. This substantial increase in revenue is primarily a result of the increased production from the certain oil and gas assets acquired at the end of 2018, but also is reflective of new drilling and enhancements to existing wells.

 

Expenses

 

The Company’s operating expenses increased by approximately 133%, or $3,505,158 to $6,125,555 for the three-month period ended March 31, 2019, from $2,620,397 in the corresponding prior period. Lease operating costs increased by approximately 158%, or $1,591,126, to 2,599,394 from $1,008,268 as compared to the three months ended March 31, 2018. DD&A expense, a non-cash expense, increased by $1,881,005, to $2,370,688 from $489,686 for the corresponding period in 2018. General and administrative expenses only reflected an increase of approximately 15%, to $1,033,345 or $132,820, when compared to $900,525 in the corresponding prior period.

 

Income (loss) from Operations

 

The Company, through the increased production coming from its latest acquisition, and controlling the cost of operations and administration, has generated an income from operations for the three months ended March 31, 2019 of $3,221,037, when compared to a loss from operations of $458,450 for the three months ended March 31, 2018.

 

 
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Other Income (Expense)

 

The Company had other income (expense) of $(15,152,518) for the three months ended March 31, 2019, as compared to $(1,366,222) for the three months ended March 31, 2018. This significant difference is primarily a result of increased interest expense and amortization of debt discount due to increased debt associated with acquisitions, and loss on commodity derivatives.

 

Net Income (Loss)

 

The Company incurred a net (loss) of $(11,931,481) during the three-month period ended March 31, 2019, compared with a net loss of $(1,552,883) for the three-month period ended March 31, 2018. The increase in net loss was mainly due to the items referred to in the analysis of operating expenses and other income (expense).

 

CRITICAL ACCOUNTING POLICIES AND ESTIMATES

 

We prepare our financial statements in conformity with GAAP, which requires management to make certain estimates and assumptions and apply judgments. We base our estimates and judgments on historical experience, current trends and other factors that management believes to be important at the time the financial statements are prepared and actual results could differ from our estimates and such differences could be material. Due to the need to make estimates about the effect of matters that are inherently uncertain, materially different amounts could be reported under different conditions or using different assumptions. On a regular basis, we review our critical accounting policies and how they are applied in the preparation of our financial statements, as well as the sufficiency of the disclosures pertaining to our accounting policies in the footnotes accompanying our financial statements. Described below are the most significant policies we apply in preparing our consolidated financial statements, some of which are subject to alternative treatments under GAAP. We also describe the most significant estimates and assumptions we make in applying these policies. See “Note 2 - Summary of Significant Accounting Policies” to our consolidated financial statements.

 

Oil and Gas Property Accounting

 

The Company uses the full cost method of accounting for its investment in oil and natural gas properties. Under this method of accounting, all costs of acquisition, exploration and development of oil and natural gas properties (including such costs as leasehold acquisition costs, geological expenditures, dry hole costs, tangible and intangible development costs and direct internal costs) are capitalized as the cost of oil and natural gas properties when incurred.

 

The full cost method requires the Company to calculate quarterly, by cost center, a “ceiling,” or limitation on the amount of properties that can be capitalized on the balance sheet. To the extent capitalized costs of oil and natural gas properties, less accumulated depletion and related deferred taxes exceed the sum of the discounted future net revenues of proved oil and natural gas reserves, the lower of cost or estimated fair value of unproved not properties subject to amortization, the cost of properties not being amortized, and the related tax amounts, such excess capitalized costs are charged to expense.

 

 
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Proved Reserves

 

Estimates of our proved reserves included in this report are prepared in accordance with U.S. SEC guidelines for reporting corporate reserves and future net revenue. The accuracy of a reserve estimate is a function of:

 

i.

the quality and quantity of available data;

 

ii.

the interpretation of that data;

 

iii.

the accuracy of various mandated economic assumptions; and

 

iv.

the judgment of the persons preparing the estimate.

 

Our proved reserve information included in this report was predominately based on estimates. Because these estimates depend on many assumptions, all of which may substantially differ from future actual results, reserve estimates will be different from the quantities of oil and gas that are ultimately recovered. In addition, results of drilling, testing and production after the date of an estimate may justify material revisions to the estimate.

 

In accordance with SEC requirements, we based the estimated discounted future net cash flows from proved reserves on the unweighted arithmetic average of the prior 12-month commodity prices as of the first day of each of the months constituting the period and costs on the date of the estimate.

 

The estimates of proved reserves materially impact depreciation, depletion, amortization and accretion (“DD&A”) expense. If the estimates of proved reserves decline, the rate at which we record DD&A expense will increase, reducing future net income. Such a decline may result from lower market prices, which may make it uneconomic to drill for and produce from higher-cost fields.

 

Asset Retirement Obligation

 

Asset retirement obligations (“ARO”) primarily represent the estimated present value of the amount we will incur to plug, abandon and remediate our producing properties at the projected end of their productive lives, in accordance with applicable federal, state and local laws. We determined our ARO by calculating the present value of estimated cash flows related to the obligation. The retirement obligation is recorded as a liability at its estimated present value as of the obligation’s inception, with an offsetting increase to proved properties. Periodic accretion of discount of the estimated liability is recorded as accretion expense in the accompanying consolidated statements of operations.

 

ARO liability is determined using significant assumptions, including current estimates of plugging and abandonment costs, annual inflation of these costs, the productive lives of wells and a risk-adjusted interest rate. Changes in any of these assumptions can result in significant revisions to the estimated ARO.

 

Commodity derivatives

 

The Company does not designate its commodities derivative instruments as hedges and therefore does not apply hedge accounting. Changes in fair value of derivative instruments subsequent to the initial measurement are recorded as change in fair value on derivative liability, in other income (expense). The estimated fair value amounts of the Company’s commodity derivative instruments have been determined at discrete points in time based on relevant market information which resulted in the Company classifying such derivatives as Level 2. Although the Company’s commodity derivative instruments are valued using public indices, as well as the Black-Sholes model, the instruments themselves are traded with unrelated counterparties and are not openly traded on an exchange.

 

 
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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

 

As a smaller reporting company as defined by Rule 12b-2 of the Securities Exchange Act of 1934, the Company is not required to provide the information under this item.

 

ITEM 4. CONTROLS AND PROCEDURES

 

Disclosure Controls and Procedures

 

The Company does not currently maintain controls and procedures that are designed to ensure that information required to be disclosed by the Company in the reports it files or submits under the Exchange Act are recorded, processed, summarized, and reported within the time periods specified by the Commission’s rules and forms. Disclosure controls and procedures would include, without limitation, controls and procedures designed to provide reasonable assurance that information required to be disclosed by the Company in the reports it files or submits under the Exchange Act is accumulated and communicated to management, including the Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure.

 

Under the supervision and with the participation of management, including the Company’s Chief Executive Officer, the effectiveness of the Company’s disclosure controls and procedures (as such term is defined in Rule 13a-15(e) and 15d-15(e) under the Exchange Act) as of March 31, 2019, have been evaluated, and, based upon this evaluation, the Company’s Chief Executive Officer has concluded that these controls and procedures are not effective in providing reasonable assurance of compliance.

 

Changes in Internal Control over Financial Reporting

 

Management and directors will continue to monitor and evaluate the effectiveness of the Company's internal controls and procedures and the Company's internal controls over financial reporting on an ongoing basis and are committed to taking further action and implementing additional enhancements or improvements, as necessary and as funds allow. There were no changes in Internal Control Over Financial Reporting during the quarter ended March 31, 2019.

 

 
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PART II—OTHER INFORMATION

 

ITEM 1. LEGAL PROCEEDINGS

 

From time to time, the Company may be involved in litigation relating to claims arising out of commercial operations in the normal course of business. As of March 31, 2019, there were no pending or threatened lawsuits that could reasonably be expected to have a material effect on the results of operations.

 

The staff (the “Staff”) of the SEC’s Division of Enforcement has notified the Company that the Staff has made a preliminary determination to recommend that the SEC file an enforcement action against the Company, as well as against its CEO and it CFO, for alleged violations of Section 17(a) of the Securities Act of 1933 and Section 10(b) of the Securities Exchange Act of 1934 and Rule 10b-5 thereunder during the period from early 2014 through late 2016. The Staff’s notice is not a formal allegation or a finding of wrongdoing by the Company, and the Company is in dialogue with the Staff regarding its preliminary determination. The Company believes it has adequate defenses and intends to vigorously defend any enforcement action that may be initiated by the SEC.

 

ITEM 1A. RISK FACTORS

 

As a smaller reporting company as defined by Rule 12b-2 of the Securities Exchange Act of 1934, the Company is not required to provide the information under this item.

 

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

 

During the quarter ended March 31, 2019, the Company issued 198,056 common shares for services.

 

The shares described above were issued pursuant to exemptions from registration requirements relying on Section 4(a)(2) of the Securities Act of 1933 and/or Rule 506 of Regulation D promulgated thereunder as there was no general solicitation, and the transactions did not involve a public offering.

 

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

 

None.

 

ITEM 4. MINE SAFETY DISCLOSURES

 

None.

 

ITEM 5. OTHER INFORMATION

 

None.

 

 
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ITEM 6. EXHIBITS

 

Number

Description

3.1

Articles of Incorporation (incorporated by reference to our Definitive Information Statement on Schedule 14C filed on October 14, 2008)

 

3.2

Bylaws (incorporated by reference to our Definitive Information Statement on Schedule 14C filed on October 14, 2008)

 

3.3

Certificate of Amendment to Articles of Incorporation (incorporated by reference to our Definitive Information Statement on Schedule 14C filed on May 23, 2012)

 

3.4

Certificate of Amendment to Articles of Incorporation (incorporated by reference to our Current Report on Form 8-K filed on November 6, 2018)

 

10.1

Membership Interest Purchase Agreement, dated November 10, 2017, by Viking Energy Group, Inc. and Black Rhino, LP (incorporated by reference to our Current Report on Form 8-K filed on December 29, 2017)

 

10.2

First Amendment to Membership Interest Purchase Agreement, dated November 30, 2017, by Viking Energy Group, Inc. and Black Rhino, LP (incorporated by reference to our Current Report on Form 8-K filed on December 29, 2017)

 

10.3

Second Amendment to Membership Interest Purchase Agreement, dated December 22, 2017, by Viking Energy Group, Inc., Black Rhino, LP, and Petrodome Energy, LLC (incorporated by reference to our Current Report on Form 8-K filed on December 29, 2017)

 

10.4

Term Loan Agreement, dated December 22, 2017, by the Borrowers listed therein, 405 Petrodome LLC, as Administrative Agent, and 405 Petrodome LLC and Cargill, Incorporated, as Lenders (incorporated by reference to our Current Report on Form 8-K filed on December 29, 2017)

 

10.5

Purchase and Sale Agreement, executed as of September 1, 2018, by and among Viking Energy Group, Inc. and Bodel Holdings, L.L.C., Cleveland Holdings, L.L.C., Delbo Holdings, L.L.C., DeQuincy Holdings, L.L.C., Gulf Coast Working Partners, L.L.C., Oakley Holdings, L.L.C., SamJam Energy, L.L.C., and Perry Point Holdings, L.L.C. (incorporated by reference to our Current Report on Form 8-K filed on September 5, 2018)

 

10.6

First Amendment to Purchase and Sale Agreement, executed as of November 1, 2018, by and among Viking Energy Group, Inc. and Bodel Holdings, L.L.C., Cleveland Holdings, L.L.C., Delbo Holdings, L.L.C., DeQuincy Holdings, L.L.C., Gulf Coast Working Partners, L.L.C., Oakley Holdings, L.L.C., SamJam Energy, L.L.C., and Perry Point Holdings, L.L.C. (incorporated by reference to our Current Report on Form 8-K filed on November 5, 2018)

 

10.7

Second Amendment to Purchase and Sale Agreement, executed as of November 1, 2018, by and among Viking Energy Group, Inc. and Bodel Holdings, L.L.C., Cleveland Holdings, L.L.C., Delbo Holdings, L.L.C., DeQuincy Holdings, L.L.C., Gulf Coast Working Partners, L.L.C., Oakley Holdings, L.L.C., SamJam Energy, L.L.C., and Perry Point Holdings, L.L.C. (incorporated by reference to our Current Report on Form 8-K filed on December 31, 2018)

 

10.8

Collateral Agreement to Purchase and Sale Agreement, executed as of December 26, 2018, by and among Viking Energy Group, Inc. and Bodel Holdings, L.L.C., Cleveland Holdings, L.L.C., Delbo Holdings, L.L.C., DeQuincy Holdings, L.L.C., Gulf Coast Working Partners, L.L.C., Oakley Holdings, L.L.C., SamJam Energy, L.L.C., and Perry Point Holdings, L.L.C. (incorporated by reference to our Current Report on Form 8-K filed on December 31, 2018)

 

10.9

Term Loan Credit Agreement, dated as of December 28, 2018, by and among Ichor Energy Holdings, LLC, Ichor Energy, LLC, ABC Funding, LLC, as Administrative Agent, and the Lender Parties (incorporated by reference to our Current Report on Form 8-K filed on December 31, 2018)

 

 
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10.10

10% Secured Promissory Note, dated December 27, 2018, issued by Viking Energy Group, Inc. to RPM Investments, a Division of Opus Bank, in favor of Sellers (incorporated by reference to our Current Report on Form 8-K filed on December 31, 2018)

 

10.11

Security and Pledge Agreement, executed as of December 27, 2018, by and among Viking Energy Group, Inc. and Bodel Holdings, L.L.C., Cleveland Holdings, L.L.C., Delbo Holdings, L.L.C., DeQuincy Holdings, L.L.C., Gulf Coast Working Partners, L.L.C., Oakley Holdings, L.L.C., SamJam Energy, L.L.C., and Perry Point Holdings, L.L.C. (incorporated by reference to our Current Report on Form 8-K filed on December 31, 2018)

 

10.12

Employment Agreement with Timothy Swift dated as of March 19, 2018 (incorporated by reference to our Quarterly Report on Form 10-Q filed on May 21, 2018)

 

10.13

Restricted Stock Agreement with Timothy Swift dated as of April 1, 2018 (incorporated by reference to our Quarterly Report on Form 10-Q filed on May 21, 2018)

 

21.1*

 

Subsidiaries of Viking Energy Group, Inc.

 

31.1*

Certification of Principal Executive Officer required by Rule 13a-14(1) or Rule 15d-14(a) of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

 

31.2*

Certification of Principal Financial and Accounting Officer required by Rule 13a-14(1) or Rule 15d-14(a) of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

 

32.1*

Certification of Principal Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 and Section 1350 of 18 U.S.C. 63

 

32.2*

Certification of Principal Financial and Accounting Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 and Section 1350 of 18 U.S.C. 63

 

99.1

Purchase, Sale and Capital Contribution Agreement effective February 1, 2016 (incorporated by reference to our Annual Report on Form 10-K/A filed on May 16, 2016)

 

99.2

Purchase and Sale Agreement (incorporated by reference to our Current Report on Form 8-K filed on September 12, 2017)

 

99.3

Purchase and Sale Agreement (incorporated by reference to our Current Report on Form 8-K filed on October 3, 2017)

 

99.4

Purchase and Sale Agreement (incorporated by reference to our Current Report on Form 8-K filed on October 4, 2017)

 

99.5

Purchase and Sale Agreement (incorporated by reference to our Current Report on Form 8-K filed on December 8, 2017)

 

101.INS**

XBRL Instance Document

 

101.SCH**

XBRL Taxonomy Extension Schema Document

 

101.CAL**

XBRL Taxonomy Extension Calculation Linkbase Document

 

101.DEF**

XBRL Taxonomy Extension Definition Linkbase Document

 

101.LAB**

XBRL Taxonomy Extension Label Linkbase Document

 

101.PRE**

XBRL Taxonomy Extension Presentation Linkbase Document

______________

* Filed herewith

** XBRL (Extensible Business Reporting Language) information is furnished and not filed or a part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, as amended, is deemed not filed for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and otherwise is not subject to liability under these sections.

 

ITEM 7. OFF BALANCE-SHEET ARRANGEMENTS

 

None.

 

 
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SIGNATURES

 

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

 

VIKING ENERGY GROUP, INC.

(Registrant)

 

 

 

 

 

/s/ James Doris

 

Date: May 14, 2019

Principal Executive Officer

 

 

  

/s/ Frank W. Barker, Jr.

 

Date: May 14, 2019

Principal Financial and Accounting Officer

 

 

 

 
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