☑
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QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
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☐
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TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
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Texas
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22-3755993
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(State
or other jurisdiction of incorporation or
organization)
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(IRS
Employer Identification No.)
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Large accelerated filer ☐
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Accelerated filer ☐
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Non-accelerated filer ☐
(Do not check if a smaller reporting
company)
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Smaller reporting company ☑
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Emerging growth company ☐
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PART I – FINANCIAL INFORMATION
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Page
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Item
1.
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Financial
Statements
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F-1
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Consolidated
Balance Sheets as of June 30, 2017 and December 31, 2016
(Unaudited)
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F-1
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Consolidated
Statements of Operations for the Three and Six Months Ended June
30, 2017 and 2016 (Unaudited)
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F-2
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Consolidated
Statements of Cash Flows for the Six Months Ended June 30, 2017 and
2016 (Unaudited)
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F-3
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Notes
to Unaudited Consolidated Financial Statements
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F-4
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Item
2.
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Management’s
Discussion and Analysis of Financial Condition and Results of
Operations
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1
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Item
3.
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Quantitative
and Qualitative Disclosures About Market Risk
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11
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Item
4.
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Controls
and Procedures
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11
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PART II – OTHER INFORMATION
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Item
1.
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Legal
Proceedings
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12
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Item
1A.
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Risk
Factors
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12
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Item
2.
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Unregistered
Sales of Equity Securities and Use of Proceeds
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14
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Item
3.
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Defaults
Upon Senior Securities
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15
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Item
4.
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Mine
Safety Disclosures
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15
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Item
5.
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Other
Information
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15
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Item
6.
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Exhibits
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15
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Signatures
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16
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June
30,
2017
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December 31,
2016
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Assets
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Current
assets:
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Cash
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$891
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$659
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Accounts
receivable
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-
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25
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Accounts receivable
– oil and gas
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416
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439
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Prepaid expenses
and other current assets
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110
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173
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Total current
assets
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1,417
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1,296
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Oil and gas
properties:
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Oil and gas
properties, subject to amortization, net
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55,874
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57,395
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Total oil and gas
properties, net
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55,874
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57,395
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Other
assets
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85
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85
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Investments –
cost method
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4
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4
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Total
assets
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$57,380
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$58,780
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Liabilities
and Shareholders’ Deficit
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Current
liabilities:
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Accounts
payable
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$80
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$103
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Accrued
expenses
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1,906
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1,802
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Revenue
payable
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524
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517
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Convertible notes
payable – Bridge Notes, net of premiums of $113,000 and
$113,000, respectively
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588
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588
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Notes payable
– Secured Promissory Notes, net of debt discount of $-0- and
$50,000, respectively
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-
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300
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Total current
liabilities
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3,098
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3,310
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Long-term
liabilities:
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Accrued
expenses
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1,022
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589
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Accrued expenses
– related party
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1,201
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677
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Notes payable
– Secured Promissory Notes, net of debt discount of
$3,625,000 and $4,600,000, respectively
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30,868
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27,497
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Notes payable
– Secured Promissory Notes – related party, net of debt
discount of $1,720,000 and $2,338,000, respectively
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14,615
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13,319
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Notes payable
– Subordinated – related party
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10,803
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10,173
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Notes payable
– other
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4,925
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4,925
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Asset retirement
obligations
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278
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246
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Total
liabilities
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66,810
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60,736
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Commitments and
contingencies
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Shareholders’
deficit:
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Series A
convertible preferred stock, $0.001 par value, 100,000,000 shares
authorized, 66,625 and 66,625 shares issued and outstanding,
respectively
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-
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-
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Common stock,
$0.001 par value, 200,000,000 shares authorized; 6,044,729 and
5,493,112 shares issued and outstanding, respectively
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6
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5
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Additional paid-in
capital
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100,781
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99,770
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Accumulated
deficit
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(110,217)
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(101,731)
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Total
shareholders’ deficit
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(9,430)
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(1,956)
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Total liabilities
and shareholders’ deficit
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$57,380
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$58,780
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For the Three
Months
Ended
June 30,
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For the Six
Months
Ended June
30,
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||
Revenue:
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2017
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2016
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2017
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2016
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Oil and gas
sales
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$812
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$1,203
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$1,546
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$1,785
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Operating
expenses:
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Lease operating
costs
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397
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414
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727
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678
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Exploration
expense
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-
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86
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-
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203
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Selling, general
and administrative expense
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694
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1,305
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1,494
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2,721
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Depreciation,
depletion, amortization and accretion
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873
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522
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1,553
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1,799
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Gain on settlement
of payables
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-
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(1,282)
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-
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(1,282)
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Total operating
expenses
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1,964
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1,045
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3,774
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4,119
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Operating income
(loss)
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(1,152)
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158
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(2,228)
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(2,334)
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Other income
(expense):
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Interest
expense
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(3,162)
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(3,592)
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(6,258)
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(7,678)
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Total other
expense
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(3,162)
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(3,592)
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(6,258)
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(7,678)
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Net
loss
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$(4,314)
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$(3,434)
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$(8,486)
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$(10,012)
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Net loss per common
share:
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Basic and
diluted
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$(0.76)
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$(0.71)
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$(1.52)
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$(2.10)
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Weighted average
number of common shares outstanding:
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Basic and
diluted
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5,687,690
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4,870,573
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5,590,938
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4,777,881
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For the Six
Months
Ended June
30,
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2017
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2016
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Cash Flows From
Operating Activities:
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Net
loss
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$(8,486)
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$(10,012)
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Adjustments to
reconcile net loss to net cash used in operating
activities:
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Stock-based
compensation expense
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517
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1,226
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Depreciation,
depletion and amortization
|
1,553
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1,799
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Interest expense
deferred and capitalized in debt restructuring
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3,384
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3,690
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Gain on settlement
of payables
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-
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(1,282)
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Amortization of
debt discount
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1,643
|
3,756
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Changes in
operating assets and liabilities:
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Accounts
receivable
|
25
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406
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Accounts receivable
- oil and gas
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23
|
180
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Accounts receivable
- related party
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-
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(2)
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Prepaid expenses
and other current assets
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63
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(30)
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Accounts
payable
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(23)
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(3,209)
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Accrued
expenses
|
537
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(3,104)
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Accrued expenses -
related parties
|
524
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(42)
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Revenue
payable
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7
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(13)
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Net cash used in
operating activities
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(233)
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(6,637)
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Cash Flows From
Investing Activities:
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Cash paid for
drilling costs
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-
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(64)
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Net cash used in
investing activities
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-
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(64)
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Cash Flows From
Financing Activities:
|
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Proceeds from notes
payable, net of offering costs
|
-
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6,295
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Repayment of notes
payable
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(30)
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-
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Cash paid for stock
repurchase and retirement
|
-
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(74)
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Proceeds from
issuance of common stock, net of issuance costs
|
495
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-
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Net provided by
financing activities
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465
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6,221
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Net increase
(decrease) in cash
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232
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(480)
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Cash at beginning
of period
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659
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1,138
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Cash at end of
period
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$891
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$658
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Supplemental
Disclosure of Cash Flow Information
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Cash paid
for:
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Interest
|
$-
|
$553
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Income
taxes
|
$-
|
$-
|
|
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Noncash Investing
and Financing Activities:
|
|
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Issuance of
restricted common stock for services upon vesting
maturity
|
$-
|
$2
|
Accrual of costs
for oil and gas properties by assumption of payables
|
$-
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$8
|
Changes in
estimates of asset retirement obligations
|
$1
|
$9
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Acquisition of oil
and gas properties
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$-
|
$3,587
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Issuance of shares
for Liberty settlement of payables
|
$-
|
$588
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Debt discount for
warrants from Tranche A debt
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$-
|
$599
|
|
2017
|
2016
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Asset retirement
obligations at January 1
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$246
|
$189
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Accretion
expense
|
33
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14
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Obligations
incurred for acquisition
|
-
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19
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Changes in
estimates
|
(1)
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(9)
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Asset retirement
obligations at June 30
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$278
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$213
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Level 1
– Quoted prices in active markets for identical assets or
liabilities.
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Level 2
– Inputs other than Level 1 that are observable, either
directly or indirectly, such as quoted prices for similar assets or
liabilities, quoted prices in markets that are not active, or other
inputs that are observable or can be corroborated by observable
market data for substantially the full term of the assets or
liabilities.
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Level 3
– Unobservable inputs that are supported by little or no
market activity and that are significant to the fair value of the
assets or liabilities.
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Balance
at
December 31,
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Balance
at
June
30,
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2016
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Additions
|
Disposals
|
Transfers
|
2017
|
Oil and gas
properties, subject to amortization
|
$68,306
|
|
$-
|
$-
|
$68,306
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Oil and gas
properties, not subject to amortization
|
-
|
-
|
-
|
-
|
-
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Asset retirement
costs
|
163
|
(1)
|
-
|
-
|
162
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Accumulated
depreciation, depletion and impairment
|
(11,074)
|
(1,520)
|
-
|
-
|
(12,594)
|
Total oil and gas
assets
|
$57,395
|
$(1,521)
|
$-
|
$-
|
$55,874
|
Assets
Acquired:
|
|
Accounts receivable
– oil and gas
|
$793
|
Oil and gas
properties, subject to amortization
|
3,587
|
Total
assets
|
$4,380
|
|
|
Liabilities
Assumed:
|
|
Accounts
payable
|
$(4,361)
|
Asset retirement
obligation
|
(19)
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Total
liabilities
|
(4,380)
|
Net purchase
price
|
$-
|
●
|
Created
and issued to the Tranche A Investors new “Tranche A
Notes,” in substantially the same form and with similar terms
as the Tranche B Notes, except as discussed below, consisting of a
term loan issuable in tranches with a maximum aggregate principal
amount of $25,960,000, with borrowed funds accruing interest at 15%
per annum, and maturing on May 11, 2019 (the “Tranche A
Maturity Date”) (the “Tranche A Notes,” and
together with the Tranche B Notes, the “New Senior
Notes”);
|
●
|
The
Company capitalized all accrued and unpaid interest under the
Tranche B Notes as a term loan with an aggregate outstanding
principal balance as of May 12, 2016 equal to $39,065,000 (as of
June 30, 2017, the aggregate outstanding principal balance is
$45,087,000). The Tranche B Notes mature on June 11, 2019 except
for the Tranche B Note issued to RJC, which matures on July 11,
2019;
|
●
|
Amended
the provisions of the Senior Notes which required mandatory
prepayments from our revenues, replacing them with a Net Revenue
Sweep as described below; and
|
●
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Provides
that interest on the Tranche B Notes will continue to accrue at the
rate of 15% per annum, but all accrued interest through December
31, 2017 shall be deferred until due and payable on the maturity
date, with all interest amounts deferred being added to the
principal of the Tranche B Notes on a monthly basis and that
following December 31, 2017, all interest will accrue and be paid
monthly in arrears in cash to the Tranche B Note holders, provided,
however, no payment may be made on the Tranche B Notes unless and
until the Tranche A Notes are repaid in full.
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(A)
|
prior
to June 1, 2014, the conversion price was $21.50 per share;
and
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(B)
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following
June 1, 2014, the denominator used in the calculation described
above is the greater of (i) 80% of the average of the closing price
per share of the Company’s publicly-traded common stock for
the five (5) trading days immediately preceding the date of the
conversion notice provided by the holder; and (ii) $5.00 per
share.
|
●
|
The
Long-Term Financing must not exceed $95 million;
|
●
|
The
Company must make commercially reasonable best efforts to include
adequate reserves or other payment provisions whereby MIEJ is paid
all interest and fees accrued on the New MIEJ Note commencing as of
March 8, 2017 and annually thereafter, and to allow for quarterly
interest payments starting March 31, 2017 of not less than 5% per
annum on the outstanding balance of the New MIEJ Note, plus a
one-time payment of accrued interest (not to exceed $500,000) as of
March 31, 2017; and
|
●
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Commencing
on March 8, 2017, MIEJ shall have the right to convert the balance
of the New MIEJ Note into the Company’s common stock at a
price equal to 80% of the average closing price per share of our
stock over the then previous 60 days, subject to a minimum
conversion price of $3.00 per share. MIEJ shall not be permitted to
convert if the conversion would result in MIEJ holding more than
19.9% of the Company’s outstanding common stock without
approval from the Company’s shareholders, which approval the
Company obtained at its 2016 annual shareholder meeting held on
December 28, 2016.
|
|
|
|
Weighted
|
|
|
|
Average
|
|
|
Weighted
|
Remaining
|
|
|
Average
|
Contract
|
|
Number
of
|
Exercise
|
Term
|
|
Shares
|
Price
|
(#
years)
|
Outstanding at
January 1, 2017
|
518,727
|
$5.00
|
4.3
|
Granted
|
-
|
-
|
-
|
Exercised
|
-
|
-
|
-
|
Forfeited and
cancelled
|
-
|
-
|
-
|
|
|
|
|
Outstanding at June
30, 2017
|
518,727
|
$5.00
|
3.8
|
|
|
|
|
Exercisable at June
30, 2017
|
451,614
|
$5.38
|
3.7
|
|
Number
of
Shares
|
Weighted
Average
Exercise
Price
|
Weighted
Average
Remaining
Contract
Term
(#
years)
|
Outstanding at
January 1, 2017
|
1,256,618
|
$8.00
|
2.4
|
Granted
|
-
|
-
|
-
|
Exercised
|
-
|
-
|
-
|
Forfeited and
cancelled
|
(8,573)
|
52.50
|
-
|
|
|
|
|
Outstanding at June
30, 2017
|
1,248,045
|
$7.70
|
1.9
|
|
|
|
|
Exercisable at June
30, 2017
|
1,248,045
|
$7.70
|
1.9
|
|
As
of
June
30,
2017
|
Accrued
expenses
|
$1,201
|
Long-term notes
payable - Secured Promissory Notes, net of discount of
$1,720,000
|
14,615
|
Long notes payable
– Subordinated
|
10,803
|
Total
liabilities
|
$26,619
|
|
Fair Value
Measurements At June 30, 2017
|
|||
|
Quoted Prices in
Active Markets for Identical Assets
|
Significant
Other Observable Inputs
|
Significant
Unobservable Inputs
|
Total Carrying
Value
|
|
(Level
1)
|
(Level
2)
|
(Level
3)
|
|
Series A
Convertible Preferred Stock
|
$-
|
$-
|
$28,402
|
$28,402
|
|
For
the
Six Months
Ended
June
30,
|
For
the
Year
Ended
December 31,
|
|
2017
|
2016
|
Deferred
Tax Assets (Liabilities)
|
|
|
Difference in
depreciation, depletion, and capitalization methods – oil and
natural gas properties
|
$(255)
|
$479
|
Net operating
losses
|
2,839
|
5,507
|
Impairment –
oil and natural gas properties
|
-
|
-
|
Other
|
27
|
438
|
Total deferred tax
asset
|
2,611
|
6,424
|
|
|
|
Less: valuation
allowance
|
(2,611)
|
(6,424)
|
Total deferred tax
assets
|
$-
|
$-
|
●
|
business
strategy;
|
●
|
reserves;
|
●
|
technology;
|
●
|
cash
flows and liquidity;
|
●
|
financial
strategy, budget, projections and operating results;
|
●
|
oil and
natural gas realized prices;
|
●
|
timing
and amount of future production of oil and natural
gas;
|
●
|
availability
of oil field labor;
|
●
|
the
amount, nature and timing of capital expenditures, including future
exploration and development costs;
|
●
|
availability
and terms of capital;
|
●
|
drilling
of wells;
|
●
|
government
regulation and taxation of the oil and natural gas
industry;
|
●
|
marketing
of oil and natural gas;
|
●
|
exploitation
projects or property acquisitions;
|
●
|
costs
of exploiting and developing our properties and conducting other
operations;
|
●
|
general
economic conditions;
|
●
|
competition
in the oil and natural gas industry;
|
●
|
effectiveness
of our risk management activities;
|
●
|
environmental
liabilities;
|
●
|
counterparty
credit risk;
|
●
|
developments
in oil-producing and natural gas-producing countries;
|
●
|
future
operating results;
|
●
|
future
acquisitions and combinations;
|
●
|
planned
debt conversions and equity investment transactions;
and
|
●
|
estimated
future reserves and the present value of such reserves; and plans,
objectives, expectations and intentions contained in this Quarterly
Report that are not historical.
|
|
Three Months Ended
June 30, 2017 |
Three Months Ended
June 30, 2016 |
Oil volume
(BBL)
|
14,296
|
29,167
|
Gas volume
(MCF)
|
36,747
|
56,973
|
Volume equivalent
(BOE) (1)
|
20,421
|
38,663
|
Revenue
(000’s)
|
$812
|
$1,203
|
|
Six Months
Ended
June
30,
2017
|
Six Months
Ended
June
30,
2016
|
Oil volume
(BBL)
|
26,222
|
48,405
|
Gas volume
(MCF)
|
55,179
|
83,215
|
Volume equivalent
(BOE) (1)
|
35,419
|
62,274
|
Revenue
(000’s)
|
$1,546
|
$1,785
|
|
For the Three
Months Ended
|
|
|
|
Ended June
30,
|
Increase/
|
|
(in
thousands)
|
2017
|
2016
|
(Decrease)
|
Payroll and related
costs
|
$267
|
$241
|
$26
|
Stock-based
compensation expense
|
241
|
724
|
(483)
|
Legal
fees
|
21
|
35
|
(14)
|
Accounting and
other professional fees
|
93
|
157
|
(64)
|
Insurance
|
27
|
25
|
2
|
Travel and
entertainment
|
1
|
1
|
-
|
Bad debt
expense
|
-0-
|
50
|
(50)
|
Office rent,
communications and other
|
44
|
72
|
(28)
|
Total selling,
general and administrative expenses
|
$694
|
$1,305
|
$(611)
|
|
For the Six
Months Ended
|
|
|
|
June
30,
|
Increase/
|
|
(in
thousands)
|
2017
|
2016
|
(Decrease)
|
Payroll and related
costs
|
$548
|
$792
|
$(244)
|
Stock-based
compensation expense
|
517
|
1,226
|
(709)
|
Legal
fees
|
45
|
50
|
(5)
|
Accounting and
other professional fees
|
201
|
263
|
(62)
|
Insurance
|
54
|
50
|
4
|
Travel and
entertainment
|
2
|
9
|
(7)
|
Bad debt expense
(recovery)
|
(25)
|
156
|
(181)
|
Office rent,
communications and other
|
152
|
175
|
(23)
|
Total selling,
general and administrative expenses
|
$1,494
|
$2,721
|
$(1,227)
|
|
PEDEVCO Corp.
|
|
|
|
|
|
|
August
10, 2017
|
By:
|
/s/ Michael
L. Peterson
|
|
|
|
Michael
L. Peterson
|
|
|
|
Chief
Executive Officer
|
|
|
|
(Principal
Executive Officer)
|
|
|
PEDEVCO Corp.
|
|
|
|
|
|
|
August 10,
2017
|
By:
|
/s/ Gregory
L. Overholtzer
|
|
|
|
Gregory
L. Overholtzer
|
|
|
|
Chief
Financial Officer
|
|
|
|
(Principal
Financial and Accounting Officer)
|
|
|
|
|
|
Incorporated By
Reference
|
||||||
Exhibit No.
|
|
Description
|
|
Form
|
|
Exhibit
|
|
Filing
Date/Period End Date
|
|
File
Number
|
|
|
|
|
|
|
|
|
|
|
|
10.1
|
|
At
Market Issuance Sales Agreement, dated September 29, 2016, by and
among PEDEVCO CORP. and National Securities
Corporation
|
|
8-K
|
|
1.1
|
|
September
29, 2016
|
|
001-35922
|
31.1*
|
|
Certification
of Chief Executive Officer Pursuant to Section 302 of the
Sarbanes-Oxley Act of 2002
|
|
|
|
|
|
|
|
|
31.2*
|
|
Certification
of Chief Financial Officer Pursuant to Section 302 of the
Sarbanes-Oxley Act of 2002
|
|
|
|
|
|
|
|
|
32.1**
|
|
Certification
of Chief Executive Officer Pursuant to 18 U.S.C. Section 1350, as
Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of
2002
|
|
|
|
|
|
|
|
|
32.2**
|
|
Certification
of Chief Financial Officer Pursuant to 18 U.S.C. Section 1350, as
Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of
2002
|
|
|
|
|
|
|
|
|
101.INS*
|
|
XBRL
Instance Document
|
|
|
|
|
|
|
|
|
101.SCH*
|
|
XBRL
Taxonomy Extension Schema Document
|
|
|
|
|
|
|
|
|
101.CAL*
|
|
XBRL
Taxonomy Extension Calculation Linkbase Document
|
|
|
|
|
|
|
|
|
101.DEF*
|
|
XBRL
Taxonomy Extension Definition Linkbase Document
|
|
|
|
|
|
|
|
|
101.LAB*
|
|
XBRL
Taxonomy Extension Label Linkbase Document
|
|
|
|
|
|
|
|
|
101.PRE*
|
|
XBRL
Taxonomy Extension Presentation Linkbase Document
|
|
|
|
|
|
|
|
|
|
1.
|
I have
reviewed this quarterly report on Form 10-Q of PEDEVCO
Corp.;
|
|
2.
|
Based
on my knowledge, this report does not contain any untrue statement
of a material fact or omit to state a material fact necessary to
make the statements made, in light of the circumstances under which
such statements were made, not misleading with respect to the
period covered by this report;
|
|
3.
|
Based
on my knowledge, the financial statements, and other financial
information included in this report, fairly present in all material
respects the financial condition, results of operations and cash
flows of the registrant as of, and for, the periods presented in
this report;
|
|
4.
|
The
registrant’s other certifying officer and I are responsible
for establishing and maintaining disclosure controls and procedures
(as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and
15d-15(e)) and internal control over financial reporting (as
defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the
registrant and have:
|
a.
|
Designed such
disclosure controls and procedures, or caused such disclosure
controls and procedures to be designed under my supervision, to
ensure that material information relating to the registrant,
including its consolidated subsidiaries, is made known to me by
others within those entities, particularly during the period in
which this report is being prepared;
|
b.
|
Designed such
internal control over financial reporting, or caused such internal
control over financial reporting to be designed under our
supervision, to provide reasonable assurance regarding the
reliability of financial reporting and the preparation of financial
statements for external purposes in accordance with generally
accepted accounting principles;
|
c.
|
Evaluated the
effectiveness of the registrant’s disclosure controls and
procedures and presented in this report my conclusions about the
effectiveness of the disclosure controls and procedures, as of the
end of the period covered by this report based on such evaluation;
and
|
d.
|
Disclosed in this
report any change in the registrant’s internal control over
financial reporting that occurred during the registrant’s
most recent fiscal quarter (the registrant’s fourth fiscal
quarter in the case of an annual report) that has materially
affected, or is reasonably likely to materially affect, the
registrant’s internal control over financial reporting;
and
|
|
5.
|
The
registrant’s other certifying officer and I have disclosed,
based on our most recent evaluation of internal control over
financial reporting, to the registrant’s auditors and the
audit committee of registrant’s board of directors (or
persons performing the equivalent functions):
|
|
a.
|
all
significant deficiencies and material weaknesses in the design or
operation of internal control over financial reporting which are
reasonably likely to adversely affect the registrant’s
ability to record, process, summarize and report financial
information; and
|
|
b.
|
any
fraud, whether or not material, that involves management or other
employees who have a significant role in the registrant’s
internal controls over financial reporting.
|
|
|
|||
|
|
|
||
|
|
|
|
|
August 10,
2017
|
By:
|
/s/ Michael
L. Peterson
|
|
|
|
|
Michael
L. Peterson
|
|
|
|
|
Chief
Executive Officer
|
|
|
|
|
(Principal
Executive Officer)
|
|
|
1.
|
I have
reviewed this quarterly report on Form 10-Q of PEDEVCO
Corp.;
|
|
2.
|
Based
on my knowledge, this report does not contain any untrue statement
of a material fact or omit to state a material fact necessary to
make the statements made, in light of the circumstances under which
such statements were made, not misleading with respect to the
period covered by this report;
|
|
3.
|
Based
on my knowledge, the financial statements, and other financial
information included in this report, fairly present in all material
respects the financial condition, results of operations and cash
flows of the registrant as of, and for, the periods presented in
this report;
|
|
4.
|
The
registrant’s other certifying officer and I are responsible
for establishing and maintaining disclosure controls and procedures
(as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and
15d-15(e)) and internal control over financial reporting (as
defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the
registrant and have:
|
a.
|
Designed such
disclosure controls and procedures, or caused such disclosure
controls and procedures to be designed under my supervision, to
ensure that material information relating to the registrant,
including its consolidated subsidiaries, is made known to me by
others within those entities, particularly during the period in
which this report is being prepared;
|
b.
|
Designed such
internal control over financial reporting, or caused such internal
control over financial reporting to be designed under our
supervision, to provide reasonable assurance regarding the
reliability of financial reporting and the preparation of financial
statements for external purposes in accordance with generally
accepted accounting principles;
|
c.
|
Evaluated the
effectiveness of the registrant’s disclosure controls and
procedures and presented in this report my conclusions about the
effectiveness of the disclosure controls and procedures, as of the
end of the period covered by this report based on such evaluation;
and
|
d.
|
Disclosed in this
report any change in the registrant’s internal control over
financial reporting that occurred during the registrant’s
most recent fiscal quarter (the registrant’s fourth fiscal
quarter in the case of an annual report) that has materially
affected, or is reasonably likely to materially affect, the
registrant’s internal control over financial reporting;
and
|
|
5.
|
The
registrant’s other certifying officer and I have disclosed,
based on our most recent evaluation of internal control over
financial reporting, to the registrant’s auditors and the
audit committee of registrant’s board of directors (or
persons performing the equivalent functions):
|
|
a.
|
all
significant deficiencies and material weaknesses in the design or
operation of internal control over financial reporting which are
reasonably likely to adversely affect the registrant’s
ability to record, process, summarize and report financial
information; and
|
|
b.
|
any
fraud, whether or not material, that involves management or other
employees who have a significant role in the registrant’s
internal controls over financial reporting.
|
|
|
|
|
August 10,
2017
|
By:
|
/s/ Gregory
L. Overholtzer
|
|
|
|
Gregory
L. Overholtzer
|
|
|
|
Chief
Financial Officer
|
|
|
|
(Principal
Financial and Accounting Officer)
|
|
1.
|
The
Report fully complies with the requirements of Section 13(a) or
15(d) of the Securities Exchange Act of 1934, as amended;
and
|
2.
|
The
information contained in the Report fairly presents, in all
material respects, the financial condition and results of
operations of the Company.
|
|
|
|
|
|
|
|
|
August 10,
2017
|
By:
|
/s/ Michael
L. Peterson
|
|
|
|
Michael
L. Peterson
|
|
|
|
Chief
Executive Officer
|
|
|
|
(Principal
Executive Officer)
|
|
1.
|
The
Report fully complies with the requirements of Section 13(a) or
15(d) of the Securities Exchange Act of 1934, as amended;
and
|
2.
|
The
information contained in the Report fairly presents, in all
material respects, the financial condition and results of
operations of the Company.
|
|
|
|
|
|
|
|
|
August 10,
2017
|
By:
|
/s/ Gregory
L. Overholtzer
|
|
|
|
Gregory
L. Overholtzer
|
|
|
|
Chief
Financial Officer
|
|
|
|
(Principal
Financial and Accounting Officer)
|
|
Document and Entity Information - shares |
6 Months Ended | |
---|---|---|
Jun. 30, 2017 |
Aug. 08, 2017 |
|
Document And Entity Information | ||
Entity Registrant Name | PEDEVCO CORP | |
Entity Central Index Key | 0001141197 | |
Document Type | 10-Q | |
Document Period End Date | Jun. 30, 2017 | |
Amendment Flag | false | |
Current Fiscal Year End Date | --12-31 | |
Is Entity a Well-known Seasoned Issuer? | No | |
Is Entity a Voluntary Filer? | No | |
Is Entity's Reporting Status Current? | Yes | |
Entity Filer Category | Smaller Reporting Company | |
Entity Common Stock, Shares Outstanding | 6,084,729 | |
Document Fiscal Period Focus | Q2 | |
Document Fiscal Year Focus | 2017 |
CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands |
Jun. 30, 2017 |
Dec. 31, 2016 |
---|---|---|
Statement of Financial Position [Abstract] | ||
Convertible notes payable - Bridge Notes, net of premium | $ 113,000 | $ 113,000 |
Notes payable - Secured Promissory Notes, net of debt discount | 0 | 50,000 |
Notes payable - Secured Promissory Notes, net of discounts | 3,625,000 | 4,600,000 |
Notes payable - Secured Promissory Notes - related party, net of debt discount | $ 1,720,000 | $ 2,338,000 |
Stockholders' equity: | ||
Series A convertible preferred stock, par value | $ 0.001 | $ 0.001 |
Series A convertible preferred stock, shares authorized | 100,000,000 | 100,000,000 |
Series A convertible preferred stock, shares issued | 66,625 | 66,625 |
Series A convertible preferred stock, shares outstanding | 66,625 | 66,625 |
Common stock, par value | $ 0.001 | $ 0.001 |
Common stock, shares authorized | 200,000,000 | 200,000,000 |
Common stock, shares issued | 6,044,729 | 5,493,112 |
Common stock, shares outstanding | 6,044,729 | 5,493,112 |
CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) - USD ($) $ in Thousands |
3 Months Ended | 6 Months Ended | ||
---|---|---|---|---|
Jun. 30, 2017 |
Jun. 30, 2016 |
Jun. 30, 2017 |
Jun. 30, 2016 |
|
Revenue: | ||||
Oil and gas sales | $ 812 | $ 1,203 | $ 1,546 | $ 1,785 |
Operating expenses: | ||||
Lease operating costs | 397 | 414 | 727 | 678 |
Exploration expense | 0 | 86 | 0 | 203 |
Selling, general and administrative expense | 694 | 1,305 | 1,494 | 2,721 |
Depreciation, depletion, amortization and accretion | 873 | 522 | 1,553 | 1,799 |
Gain on settlement of payables | 0 | (1,282) | 0 | (1,282) |
Total operating expenses | 1,964 | 1,045 | 3,774 | 4,119 |
Operating income (loss) | (1,152) | 158 | (2,228) | (2,334) |
Other income (expense): | ||||
Interest expense | (3,162) | (3,592) | (6,258) | (7,678) |
Total other expense | (3,162) | (3,592) | (6,258) | (7,678) |
Net loss | $ (4,314) | $ (3,434) | $ (8,486) | $ (10,012) |
Net loss per common share: | ||||
Basic and diluted | $ (0.76) | $ (0.71) | $ (1.52) | $ (2.10) |
Weighted average number of common shares outstanding: | ||||
Basic and diluted | 5,687,690 | 4,870,573 | 5,590,938 | 4,777,881 |
1. BASIS OF PRESENTATION |
6 Months Ended |
---|---|
Jun. 30, 2017 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
BASIS OF PRESENTATION | The accompanying consolidated financial statements of PEDEVCO CORP. (“PEDEVCO” or the “Company”) have been prepared in accordance with generally accepted accounting principles in the United States of America (“GAAP”) and the rules of the Securities and Exchange Commission (“SEC”) and should be read in conjunction with the audited financial statements and notes thereto contained in PEDEVCO’s latest Annual Report filed with the SEC on Form 10-K. In the opinion of management, all adjustments, consisting of normal recurring adjustments, 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. Notes to the financial statements that would substantially duplicate disclosures contained in the audited financial statements for the most recent fiscal year, as reported in the Annual Report on Form 10-K for the year ended December 31, 2016, filed with the SEC on March 27, 2017, have been omitted.
The Company’s consolidated financial statements include the accounts of the Company, its wholly-owned subsidiaries and subsidiaries in which the Company has a controlling financial interest. All significant inter-company accounts and transactions have been eliminated in consolidation.
The Company completed a 1-for-10 reverse split of its outstanding common stock, which took effect as of market close on April 7, 2017. All outstanding shares, options, warrants, preferred stock and other securities convertible into the Company's common stock have been retrospectively adjusted to reflect the reverse stock split as required by the terms of such securities with a proportional increase in the related share or exercise price. |
2. DESCRIPTION OF BUSINESS |
6 Months Ended |
---|---|
Jun. 30, 2017 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
DESCRIPTION OF BUSINESS | PEDEVCO’s primary business plan is engaging in the acquisition, exploration, development and production of oil and natural gas shale plays in the United States, with a secondary focus on conventional oil and natural gas plays. The Company’s principal operating properties are located in the Wattenberg, Wattenberg Extension, and Niobrara formation in the Denver-Julesburg Basin (the “D-J Basin” and the “D-J Basin Asset”) in Weld County, Colorado, all of which properties are owned by the Company through its wholly-owned subsidiary, Red Hawk Petroleum, LLC (“Red Hawk”).
The Company plans to focus on the development of shale oil and gas assets held by the Company in its D-J Basin Asset.
The Company plans to seek additional shale oil and gas and conventional oil and gas asset acquisition opportunities in the U.S. utilizing its strategic relationships and technologies that may provide the Company a competitive advantage in accessing and exploring such assets. Some or all of these assets may be acquired by existing subsidiaries or other entities that may be formed at a future date. |
3. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Jun. 30, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Accounting Policies [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES | Basis of Presentation and Principles of Consolidation. The consolidated financial statements herein have been prepared in accordance with GAAP and include the accounts of the Company and those of its wholly and partially-owned subsidiaries as follows: (i) Blast AFJ, Inc., a Delaware corporation; (ii) Pacific Energy Development Corp. (“PEDCO”), a Nevada corporation; (iii) Pacific Energy & Rare Earth Limited, a Hong Kong company (which is currently in the process of being dissolved); (iv) Blackhawk Energy Limited, a British Virgin Islands company (which is currently in the process of being dissolved); (v) White Hawk Petroleum, LLC, a Nevada limited liability company (dissolved on November 30, 2016); (vi) Red Hawk Petroleum, LLC, a Nevada limited liability company; (vii) Pacific Energy Development MSL, LLC (owned 50% by us) (which was dissolved in September 2016) and is included in our consolidated results for the periods prior to its dissolution (“PEDCO MSL”); (viii) PEDEVCO Acquisition Subsidiary, Inc., a Texas corporation which was formed on May 21, 2015 in connection with the planned reorganization transaction with Dome Energy, Inc. (“Dome Energy”), which was subsequently terminated (which was dissolved in April 2016); and (ix) White Hawk Energy, LLC, a Delaware limited liability company, formed on January 4, 2016 in connection with the contemplated reorganization transaction with GOM Holdings, LLC (“GOM”), which reorganization transaction has since been terminated. All significant intercompany accounts and transactions have been eliminated.
Use of Estimates in Financial Statement Preparation. The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, as well as certain financial statement disclosures. While management believes that the estimates and assumptions used in the preparation of the financial statements are appropriate, actual results could differ from these estimates. Significant estimates generally include those with respect to the amount of recoverable oil and gas reserves, the fair value of financial instruments, oil and gas depletion, asset retirement obligations, and stock-based compensation.
Cash and Cash Equivalents. The Company considers all highly liquid investments with original maturities of three months or less to be cash equivalents. As of June 30, 2017, and December 31, 2016, cash equivalents consisted of money market funds and cash on deposit.
Concentrations of Credit Risk. Financial instruments which potentially subject the Company to concentrations of credit risk include cash deposits placed with financial institutions. The Company maintains its cash in bank accounts which, at times, may exceed federally insured limits as guaranteed by the Federal Deposit Insurance Corporation (“FDIC”). At June 30, 2017, approximately $391,000 of the Company’s cash balances were uninsured. The Company has not experienced any losses on such accounts.
Sales to one customer comprised 56% of the Company’s total oil and gas revenues for the six months ended June 30, 2017. Sales to one customer comprised 58% of the Company’s total oil and gas revenues for the six months ended June 30, 2016. The Company believes that, in the event that its primary customers are unable or unwilling to continue to purchase the Company’s production, there are a substantial number of alternative buyers for its production at comparable prices.
Accounts Receivable. Accounts receivable typically consist of oil and gas receivables. The Company has classified these as short-term assets in the balance sheet because the Company expects repayment or recovery within the next 12 months. The Company evaluates these accounts receivable for collectability considering the results of operations of these related entities and, when necessary, records allowances for expected unrecoverable amounts. To date, no allowances have been recorded. Included in accounts receivable - oil and gas is $-0- related to receivables from joint interest owners.
Bad Debt Expense. The Company’s ability to collect outstanding receivables is critical to its operating performance and cash flows. Accounts receivable are stated at an amount management expects to collect from outstanding balances. The Company extends credit in the normal course of business. The Company regularly reviews outstanding receivables and when the Company determines that a party may not be able to make required payments, a charge to bad debt expense in the period of determination is made. Though the Company’s bad debts have not historically been significant, the Company could experience increased bad debt expense should a financial downturn occur.
Equipment. Equipment is stated at cost less accumulated depreciation and amortization. Maintenance and repairs are charged to expense as incurred. Renewals and betterments which extend the life or improve existing equipment are capitalized. Upon disposition or retirement of equipment, the cost and related accumulated depreciation are removed and any resulting gain or loss is reflected in operations. Depreciation is provided using the straight-line method over the estimated useful lives of the assets, which are 3 to 10 years.
Oil and Gas Properties, Successful Efforts Method. The successful efforts method of accounting is used for oil and gas exploration and production activities. Under this method, all costs for development wells, support equipment and facilities, and proved mineral interests in oil and gas properties are capitalized. Geological and geophysical costs are expensed when incurred. Costs of exploratory wells are capitalized as exploration and evaluation assets pending determination of whether the wells find proved oil and gas reserves. Proved oil and gas reserves are the estimated quantities of crude oil and natural gas which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions, (i.e., prices and costs as of the date the estimate is made). Prices include consideration of changes in existing prices provided only by contractual arrangements, but not on escalations based upon future conditions.
Exploratory wells in areas not requiring major capital expenditures are evaluated for economic viability within one year of completion of drilling. The related well costs are expensed as dry holes if it is determined that such economic viability is not attained. Otherwise, the related well costs are reclassified to oil and gas properties and subject to impairment review. For exploratory wells that are found to have economically viable reserves in areas where major capital expenditure will be required before production can commence, the related well costs remain capitalized only if additional drilling is under way or firmly planned. Otherwise the related well costs are expensed as dry holes.
Exploration and evaluation expenditures incurred subsequent to the acquisition of an exploration asset in a business combination are accounted for in accordance with the policy outlined above.
Depreciation, depletion and amortization of capitalized oil and gas properties is calculated on a field by field basis using the unit of production method. Lease acquisition costs are amortized over the total estimated proved developed and undeveloped reserves and all other capitalized costs are amortized over proved developed reserves.
Impairment of Long-Lived Assets. The Company reviews the carrying value of its long-lived assets annually or whenever events or changes in circumstances indicate that the historical cost-carrying value of an asset may no longer be appropriate. The Company assesses recoverability of the carrying value of the asset by estimating the future net undiscounted cash flows expected to result from the asset, including eventual disposition. If the future net undiscounted cash flows are less than the carrying value of the asset, an impairment loss is recorded equal to the difference between the asset’s carrying value and estimated fair value.
Asset Retirement Obligations. If a reasonable estimate of the fair value of an obligation to perform site reclamation, dismantle facilities or plug and abandon wells can be made, the Company will record a liability (an asset retirement obligation or “ARO”) on its consolidated balance sheet and capitalize the present value of the asset retirement cost in oil and gas properties in the period in which the retirement obligation is incurred. In general, the amount of an ARO and the costs capitalized will be equal to the estimated future cost to satisfy the abandonment obligation assuming the normal operation of the asset, using current prices that are escalated by an assumed inflation factor up to the estimated settlement date, which is then discounted back to the date that the abandonment obligation was incurred using an assumed cost of funds for the Company. After recording these amounts, the ARO will be accreted to its future estimated value using the same assumed cost of funds and the capitalized costs are depreciated on a unit-of-production basis over the estimated proved developed reserves. Both the accretion and the depreciation will be included in depreciation, depletion and amortization expense on our consolidated statements of operations.
The following table describes changes in our asset retirement obligations during the six months ended June 30, 2017 and 2016 (in thousands):
Revenue Recognition. All revenue is recognized when persuasive evidence of an arrangement exists, the service or sale is complete, the price is fixed or determinable and collectability is reasonably assured. Revenue is derived from the sale of crude oil and natural gas. Revenue from crude oil and natural gas sales is recognized when the product is delivered to the purchaser and collectability is reasonably assured. The Company follows the “sales method” of accounting for oil and natural gas revenue, so it recognizes revenue on all natural gas or crude oil sold to purchasers, regardless of whether the sales are proportionate to its ownership in the property. A receivable or liability is recognized only to the extent that the Company has an imbalance on a specific property greater than its share of the expected remaining proved reserves. If collection is uncertain, revenue is recognized when cash is collected.
Income Taxes. The Company utilizes the asset and liability method in accounting for income taxes. Under this method, deferred tax assets and liabilities are recognized for operating loss and tax credit carry-forwards and for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the year in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in the results of operations in the period that includes the enactment date. A valuation allowance is recorded to reduce the carrying amounts of deferred tax assets unless it is more likely than not that the value of such assets will be realized.
Stock-Based Compensation. The Company utilizes the Black-Scholes option pricing model to estimate the fair value of employee stock option awards at the date of grant, which requires the input of highly subjective assumptions, including expected volatility and expected life. Changes in these inputs and assumptions can materially affect the measure of estimated fair value of our share-based compensation. These assumptions are subjective and generally require significant analysis and judgment to develop. When estimating fair value, some of the assumptions will be based on, or determined from, external data and other assumptions may be derived from our historical experience with stock-based payment arrangements. The appropriate weight to place on historical experience is a matter of judgment, based on relevant facts and circumstances.
The Company estimates volatility by considering the historical stock volatility. The Company has opted to use the simplified method for estimating expected term, which is generally equal to the midpoint between the vesting period and the contractual term.
Loss per Common Share. Basic loss per common share equals net loss divided by weighted average common shares outstanding during the period. Diluted loss per share includes the impact on dilution from all contingently issuable shares, including options, warrants and convertible securities. The common stock equivalents from contingent shares are determined by the treasury stock method. The Company incurred net losses for the six months ended June 30, 2017 and 2016, and therefore, basic and diluted loss per share for those periods are the same as all potential common equivalent shares would be anti-dilutive. The Company excluded 451,614 and 342,734 potentially issuable shares of common stock related to options, 1,248,045 and 1,376,609 potentially issuable shares of common stock related to warrants and 144,822 and 133,422 potentially issuable shares of common stock related to the conversion of Bridge Notes due to their anti-dilutive effect for the six months ended June 30, 2017 and 2016, respectively.
Fair Value of Financial Instruments. The Company follows Fair Value Measurement (“ASC 820”), which clarifies fair value as an exit price, establishes a hierarchal disclosure framework for measuring fair value, and requires extended disclosures about fair value measurements. The provisions of ASC 820 apply to all financial assets and liabilities measured at fair value.
As defined in ASC 820, fair value, clarified as an exit price, represents the amount that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. As a result, fair value is a market-based approach that should be determined based on assumptions that market participants would use in pricing an asset or a liability.
As a basis for considering these assumptions, ASC 820 defines a three-tier value hierarchy that prioritizes the inputs used in the valuation methodologies in measuring fair value.
The fair value hierarchy also requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value.
Recently Issued Accounting Pronouncements. In August 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-15, Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern. The new standard requires management to assess the company’s ability to continue as a going concern. Disclosures are required if there is substantial doubt as to the Company’s continuation as a going concern within one year after the issue date of financial statements. The standard provides guidance for making the assessment, including consideration of management’s plans which may alleviate doubt regarding the Company’s ability to continue as a going concern. ASU 2014-15 is effective for years ending after December 15, 2016. The Company adopted this standard for the six months ended June 30, 2017 and the year ended December 31, 2016, and management has concluded that there is substantial doubt as to the Company’s continuation as a going concern within one year after the issue date of the financial statements.
In May 2014, the FASB issued a comprehensive new revenue recognition standard that will supersede nearly all existing revenue recognition guidance under U.S. GAAP. The standard’s core principle (issued as ASU 2014-09 by the FASB), is that a company will recognize revenue when it transfers promised goods or services to customers in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services. These may include identifying performance obligations in the contract, estimating the amount of variable consideration to include in the transaction price and allocating the transaction price to each separate performance obligation. The new guidance must be adopted using either a full retrospective approach for all periods presented in the period of adoption or a modified retrospective approach. In August 2015, the FASB issued ASU No. 2015-14, which defers the effective date of ASU 2014-09 by one year, and would allow entities the option to early adopt the new revenue standard as of the original effective date. This ASU is effective for public reporting companies for interim and annual periods beginning after December 15, 2017. The Company has evaluated the adoption of the standard and due to the nature of the Company’s oil and gas revenue agreements method there will be no impact of the standard on its consolidated financial statements.
In April 2016, the FASB issued ASU No. 2016-10, “Revenue from Contracts with Customers: Identifying Performance Obligations and Licensing” (topic 606). In March 2016, the FASB issued ASU No. 2016-08, “Revenue from Contracts with Customers: Principal versus Agent Considerations (Reporting Revenue Gross verses Net)” (topic 606). These amendments provide additional clarification and implementation guidance on the previously issued ASU 2014-09, “Revenue from Contracts with Customers”. The amendments in ASU 2016-10 provide clarifying guidance on materiality of performance obligations; evaluating distinct performance obligations; treatment of shipping and handling costs; and determining whether an entity's promise to grant a license provides a customer with either a right to use an entity's intellectual property or a right to access an entity's intellectual property. The amendments in ASU 2016-08 clarify how an entity should identify the specified good or service for the principal versus agent evaluation and how it should apply the control principle to certain types of arrangements. The adoption of ASU 2016-10 and ASU 2016-08 is to coincide with an entity's adoption of ASU 2014-09, which would be adopted for interim and annual reporting periods beginning after December 15, 2017. The Company has evaluated the adoption of the standard and due to the nature of the Company’s oil and gas revenue agreements method there will be no impact of the standard on its consolidated financial statements.
In February 2016, the FASB issued ASU 2016-02, a new lease standard requiring lessees to recognize lease assets and lease liabilities for most leases classified as operating leases under previous U.S. GAAP. The guidance is effective for fiscal years beginning after December 15, 2018, with early adoption permitted. The Company will be required to use a modified retrospective approach for leases that exist or are entered into after the beginning of the earliest comparative period in the financial statements. The Company has evaluated the adoption of the standard and due to only one operating lease currently in place there will be minimal impact of the standard on its consolidated financial statements.
In April 2016, the FASB issued ASU No. 2016-09, “Compensation – Stock Compensation” (topic 718). The FASB issued this update to improve the accounting for employee share-based payments and affect all organizations that issue share-based payment awards to their employees. Several aspects of the accounting for share-based payment award transactions are simplified, including: (a) income tax consequences; (b) classification of awards as either equity or liabilities; and (c) classification on the statement of cash flows. The updated guidance is effective for annual periods beginning after December 15, 2016, including interim periods within those fiscal years. Early adoption of the update is permitted. The Company has evaluated the adoption of the standard and due to the nature of the Company’s employee share-based payments there will be no impact of the standard on its consolidated financial statements.
In August 2016, the FASB issued ASU 2016-15, “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments” (“ASU 2016-15”). ASU 2016-15 will make eight targeted changes to how cash receipts and cash payments are presented and classified in the statement of cash flows. ASU 2016-15 is effective for fiscal years beginning after December 15, 2017. The new standard will require adoption on a retrospective basis unless it is impracticable to apply, in which case it would be required to apply the amendments prospectively as of the earliest date practicable. The Company is currently in the process of evaluating the impact of ASU 2016-15 on its consolidated financial statements.
In November 2016, the FASB issued ASU 2016-18, “Statement of Cash Flows (Topic 230)”, requiring that the statement of cash flows explain the change in the total cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. This guidance is effective for fiscal years, and interim reporting periods therein, beginning after December 15, 2017 with early adoption permitted. The provisions of this guidance are to be applied using a retrospective approach which requires application of the guidance for all periods presented. The Company is currently evaluating the impact of the new standard.
The Company does not expect the adoption of any recently issued accounting pronouncements to have a significant impact on its financial position, results of operations, or cash flows.
Subsequent Events. The Company has evaluated all transactions through the date the consolidated financial statements were issued for subsequent event disclosure consideration.
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4. GOING CONCERN |
6 Months Ended |
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Jun. 30, 2017 | |
Going Concern | |
GOING CONCERN | Although the Company’s senior Tranche A Notes (as defined and discussed below under “Note 8 – Notes Payable – 2016 Senior Note Restructuring”) do not mature until May 11, 2019 and all of the Company’s other debt expressly subordinated thereto due, June 11, 2019, at the earliest, with no amounts due or owing under such subordinated debt until such date, with the exception of the New MIEJ Note (as defined and discussed below under “Note 8 – Notes Payable – MIE Jurassic Energy Corporation”), which matures on March 8, 2019 and with interest accruing thru March 8, 2018 being payable on such date, the realization of the Company’s assets and satisfaction of its liabilities remains contingent on the completion of a future financing. The Company anticipates that it will need approximately $11 million in 2017 to execute its current business plan and is currently actively negotiating the necessary financing. In the event that the Company is unable to complete the financing currently under consideration, and is otherwise unable to replace such financing on a timely basis, it would materially affect the Company’s ability to continue as a going concern. If such financing is not completed, among other things, the Company expects that it would incur an impairment of its oil and gas properties in the range of $27 million and the Company’s ability to meet its obligations from existing cash flows would be significantly affected. If the Company would be required to seek financing from other sources, such financings may not be available or, if available, may not be on terms acceptable to the Company or its existing lenders. Accordingly, the consolidated financial statements do not include any adjustments related to the recoverability of assets or classification of liabilities that might be necessary should the Company be unable to continue as a going concern. The ability of the Company to continue as a going concern is dependent upon its ability to raise capital to meet its debt obligations, working capital needs, and develop its oil and gas properties to attain profitable operations. Management has concluded that there is substantial doubt as to the Company’s ability to continue as a going concern within one year after the issuance date of these financial statements.
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5. OIL AND GAS PROPERTIES |
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Oil and Gas Property [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
OIL AND GAS PROPERTIES | The following table summarizes the Company’s oil and gas activities by classification for the six months ended June 30, 2017 and the year ended December 31, 2016:
The depletion recorded for production on proved properties for the three and six months ended June 30, 2017 and 2016, amounted to $862,000 compared to $513,000 and $1,520,000 compared to $1,785,000, respectively.
Acquisition of Properties from Dome Energy, Inc.
On November 19, 2015, the Company entered into a Letter Agreement with certain parties including Dome Energy AB and its wholly-owned subsidiary Dome Energy, Inc. (collectively “Dome Energy”), pursuant to which Dome Energy agreed to acquire the Company’s interests in eight wells and fully fund the Company’s proportionate share of all the corresponding working interest owner expenses with respect to these eight wells. The Company assigned its interests in these wells to Dome Energy effective November 18, 2015, and Dome Energy assumed all amounts owed for the drilling and completion costs corresponding to these interests acquired from the Company.
On March 29, 2016, the Company entered into a Settlement Agreement with Dome Energy, pursuant to which Dome Energy re-conveyed to the Company the interests in these eight wells assigned to Dome Energy by the Company on November 18, 2015, with the Company becoming responsible for its proportionate share of all the working interest owner expenses, and having the right to receive all corresponding revenues with respect to these eight wells, from the initial production date of the wells. As part of this transaction, the Company also settled $659,000 of outstanding payables due from the Company to Dome Energy that was accounted for as a purchase price adjustment to the value of the oil and gas properties acquired. The transaction was closed on May 12, 2016.
The following tables summarize the allocation of the purchase price to the net assets acquired (in thousands):
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6. ACCOUNTS RECEIVABLE |
6 Months Ended |
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Jun. 30, 2017 | |
Receivables [Abstract] | |
ACCOUNTS RECEIVABLE | On November 18, 2015, when the Company assigned its interests in the eight wells to Dome Energy (as described above in Note 5), Dome Energy also agreed to pay an additional $250,000 to the Company in the event the anticipated merger was not consummated. In connection with the assignment of these well interests, Dome Energy issued a contingent promissory note to the Company, dated November 19, 2015 (the “Dome Promissory Note”), with a principal amount of $250,000, which was due to mature on December 29, 2015, upon the termination of the anticipated merger with Dome Energy. To guarantee payment of the Dome Promissory Note, Dome Energy deposited $250,000 into an escrow account. During the year ended December 31, 2016, the Company collected this receivable of $250,000 in full satisfaction of the Dome Promissory Note.
On March 24, 2015, Red Hawk and Dome Energy entered into a Service Agreement, pursuant to which Red Hawk agreed to provide certain human resource and accounting services to Dome Energy, of which $156,000 remained due and payable by Dome Energy to Red Hawk as of December 31, 2015. On March 29, 2016, the Company entered into a Settlement Agreement with Dome Energy and certain of its affiliated entities, pursuant to which the Company and Dome Energy agreed to terminate and cancel the Service Agreement and settle a number of outstanding matters, with Dome Energy agreeing to pay to Red Hawk $50,000 on May 2, 2016, in full satisfaction of the amounts due under the Service Agreement, with all remaining amounts owed forgiven by Red Hawk. As of December 31, 2015, the receivable due from Dome Energy totaled $406,000. During the year ended December 31, 2016, the net receivable created by the Dome Promissory Note was reduced to $25,000 by (i) the collection of the $250,000 as described above, (ii) forgiveness by the Company of $106,000 due from Dome Energy pursuant to the Settlement Agreement, and (iii) the recording of an allowance of $25,000 as a doubtful account (which was recognized as bad debt expense in selling, general and administrative expense on the Company’s income statement). As of December 31, 2016, the $50,000 was still due from Dome to Red Hawk as a part of the Settlement Agreement. The Company recorded an allowance for doubtful accounts as of December 31, 2016 of $25,000 related to this outstanding amount, as $25,000 of the $50,000 was collected in early 2017. During the three months ended March 31, 2017, the net receivable created by the Dome Promissory Note was equal to $25,000 due to (i) the collection of the $25,000 in January 2017, and (ii) the reversal of the allowance of $25,000 as a doubtful account (and credited to bad debt expense in selling, general and administrative expense on the Company’s income statement) due to the collection in April 2017 of the final $25,000 that had been due (the Company had no allowance for doubtful accounts as of March 31, 2017). As of June 30, 2017, the net receivable created by the Dome Promissory Note was $-0-, due to the collection of the $25,000 in April 2017 that represented the final amount due.
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7. OTHER CURRENT ASSETS |
6 Months Ended |
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Jun. 30, 2017 | |
Investments, Debt and Equity Securities [Abstract] | |
OTHER CURRENT ASSETS | On September 11, 2013, the Company entered into a Shares Subscription Agreement (“SSA”) to acquire an approximate 51% ownership in Asia Sixth Energy Resources Limited (“Asia Sixth”), which held an approximate 60% ownership interest in Aral Petroleum Capital Limited Partnership (“Aral”), a Kazakhstan entity. In August 2014 the SSA was restructured (the “Aral Restructuring”), in connection with which the Company received a promissory note in the principal amount of $10.0 million from Asia Sixth (the “A6 Promissory Note”), which would be converted into a 10.0% interest in Caspian Energy, Inc. (“Caspian Energy”), an Ontario, Canada company listed on the NEX board of the TSX Venture Exchange, upon the consummation of the Aral Restructuring.
The Company entered into an agreement with Golden Globe Energy (US), LLC (“GGE”) to convey 50% of our interests in Asia Sixth in connection with an acquisition transaction in March 2014.
The Aral Restructuring was consummated on May 20, 2015, upon which date the A6 Promissory Note was converted into 23,182,880 shares of common stock of Caspian Energy. In addition, on the date of conversion of the A6 Promissory Note, Mr. Frank Ingriselli, our Chairman and then Chief Executive Officer, was appointed as a non-executive director of Caspian Energy and currently serves as the Chairman of its Board of Directors.
In February 2015, we expanded our D-J Basin position through the acquisition of acreage from GGE (the “GGE Acquisition” and the “GGE Acquired Assets”). In connection with our GGE Acquisition, on February 23, 2015, we provided GGE a one-year option to acquire our interest in Caspian Energy for $100,000 payable upon exercise of the option recorded in prepaid expenses and other current assets. As a result, the carrying value of the 23,182,880 shares of common stock of Caspian Energy which were issued upon conversion of the A6 Promissory Note at December 31, 2015 was $100,000. The option provided to GGE was not exercised and expired on February 23, 2016, resulting in the Company retaining ownership of the 23,182,880 shares of Caspian Energy.
In connection with the Company’s May 2016 debt restructuring as more fully described below under “Note 8 – Notes Payable – 2016 Senior Note Restructuring”, the Company entered into a new Call Option Agreement with GGE, dated May 12, 2016 (the “GGE Option Agreement”), pursuant to which the Company provided GGE an option to purchase the 23,182,880 common shares of Caspian Energy upon payment of $100,000 by GGE to the Company at any time. The option expires on May 12, 2019, which is the maturity date of the debt evidenced by that certain Note and Security Agreement, dated April 10, 2014, as amended on February 23, 2015, and May 12, 2016, issued by the Company to RJ Credit LLC (“RJC” and the “RJC Junior Note”), as described below. The $100,000 option is classified as part of other current assets as of June 30, 2017.
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8. NOTES PAYABLE |
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Debt Disclosure [Abstract] | |||||||||||||||||||
NOTES PAYABLE | Note Purchase Agreement and Sale of Secured Promissory Notes
On March 7, 2014, the Company entered into a $50 million financing facility (the “Notes Purchase Agreement”) between the Company, BRe BCLIC Primary, BRe BCLIC Sub, BRe WNIC 2013 LTC Primary, BRe WNIC 2013 LTC Sub, and RJC, as investors (collectively, the “Investors”), and BAM Administrative Services LLC, as agent for the Investors (the “Agent”). The Company issued the Investors Secured Promissory Notes in the aggregate principal amount of $34.5 million (the “Initial Notes”), which also provided for an additional $15.5 million available under the financing agreement to fund the Company’s future drilling costs to be evidenced by notes with substantially similar terms as the Initial Notes (the “Subsequent Notes,” and together with the Initial Notes, the “Senior Notes”). On March 19, 2015, BRe WNIC 2013 LTC Primary transferred a portion of its Initial Note to HEARTLAND Bank, and effective April 1, 2015, BRe BCLIC Primary transferred its Initial Note to Senior Health Insurance Company of Pennsylvania (“SHIP”), with each of HEARTLAND Bank and SHIP becoming an “Investor” for purposes of the discussion below.
The Initial Notes, as originally issued, accrued interest at the rate of 15% per annum, payable monthly, required us to make certain mandatory principal payments and was originally to mature on March 7, 2017.
On August 28, 2015, January 29, 2016, March 7, 2016 and April 1, 2016, the Company entered into several letter agreements and amendments with certain of the holders to: (i) defer until the maturity date of their Senior Notes the mandatory principal payments that would otherwise be due and payable by the Company to them on payment dates occurring from August 2015 through April 2016; and (ii) defer until the maturity date of their Senior Notes and the RJC Junior Note all of the interest payments that would otherwise be due and payable by the Company to them from August 2015 to April 2016, with all interest amounts deferred being added to principal on the first business day of the month following the month in which such deferred interest is accrued. The purpose of these deferrals was to provide the Company with temporary relief from cash requirements to focus and execute upon its contemplated business combinations.
During the three and six months ended June 30, 2017, there were no payments made to reduce the outstanding principal due under the Initial Notes, however, such Notes were restructured as described below.
2016 Senior Note Restructuring
Following a series of temporary payment deferrals as described above, on May 12, 2016 (the “Closing Date”), the Company entered into an Amended and Restated Note Purchase Agreement (the “Amended NPA”), with existing lenders SHIP, BRe BCLIC Sub, BRe WINIC 2013 LTC Primary, BRe WNIC 2013 LTC Sub, Heartland Bank, and RJC, and new lenders BHLN-Pedco Corp. (“BHLN”) and BBLN-Pedco Corp. (“BBLN,” and together with BHLN and RJC, the “Tranche A Investors”) (the investors in the Tranche B Notes (defined below) and the Tranche A Investors, collectively, the “Lenders”), and the Agent, as agent for the Lenders. The Amended NPA amended and restated the Senior Notes held by the Investors, and the Company issued new Senior Secured Promissory Notes to each of the Investors (collectively, the “Tranche B Notes”) in a transaction that qualified as a troubled debt restructuring. RJC is also a party to the RJC Junior Note (discussed below under "Notes Payable - Related Party Financings - Subordinated Note Payable Assumed”).
Subsequently, certain of the Lenders transferred some or all of the principal outstanding under the New Senior Notes (as defined below) held by them and the term Lenders as used herein refers to the current holders of the New Senior Notes, as applicable.
The Amended NPA amended the Senior Notes as follows:
The Tranche A Notes are substantially similar to the Tranche B Notes, except that such notes are senior to the Tranche B Notes, accrue interest until maturity and have priority to the payment of Monthly Net Revenues as discussed below. Amounts paid to the Agent through the Net Revenue Sweep are applied first to the repayment of principal and interest due under the Tranche A Notes until such notes are paid in full and then to the repayment of principal and interest amounts due under the Tranche B Notes. As of June 30, 2017, the Company has paid $682,000 of principal under the Net Revenue Sweep, of which $30,000 was paid during the current six month period.
On the Closing Date, Tranche A Investors BHLN and BBLN loaned the Company their pro rata share of an aggregate of $6,422,000 (the “Initial Tranche A Funding”). The Initial Tranche A Funding net proceeds (amounting to $6,422,000 less legal fees of $127,000) were used by the Company to (i) fund approximately $5.1 million due to a third party operator for drilling and completion expenses related to the acquired working interests in eight wells from Dome Energy, (ii) pay $750,000 of the Company’s past due payables to Liberty (defined below under “Note 9 – Commitments and Contingencies” – “Other Commitments”), (iii) pay $445,000 of unpaid interest payments due to Heartland Bank under its Tranche B Note through February 29, 2016, and (iv) pay fees and expenses of $127,000.
Subject to the terms and conditions of the Amended NPA, the Company may request each Tranche A Investor, from time to time, to advance to the Company additional amounts of funding (each, a “Subsequent Tranche A Funding”), provided that: (i) the Company may not request a Subsequent Tranche A Funding more than one time in any calendar month; (ii) Agent shall have received a written request from the Company at least 15 business days prior to the requested date of such advance (the “Advance Request”); (iii) no Event of Default shall have occurred and be continuing; and (iv) the Company shall provide to the Agent such documents, instruments, certificates and other writings as the Agent shall reasonably require in its sole and absolute discretion. The advancement of all or any portion of the Subsequent Tranche A Funding is in the sole and absolute discretion of the Agent and the Investors and no Investor is obligated to fund all or any part of the Subsequent Tranche A Funding. Each Subsequent Tranche A Funding shall be in a minimum amount of $500,000 and multiples of $100,000 in excess thereof. The aggregate amount of Subsequent Tranche A Fundings that may be made by the Investors under the Amended NPA shall not exceed $18,577,876 and any Subsequent Tranche A Funding repaid may not be re-borrowed.
In addition, subject to the terms and conditions of the Amended NPA, RJC agreed to loan $240,000 to the Company, within 30 days of the Closing Date and within 30 days of each of July 1, 2016, October 1, 2016 and January 1, 2017 (collectively, the “RJC Fundings” and collectively with the Investor Tranche A Fundings, the “Fundings”), provided that no Event of Default or Default shall exist. The aggregate amount of the RJC Fundings made by RJC under the Amended NPA shall not exceed $960,000 and any Funding repaid may not be re-borrowed. As of June 30, 2017, the Company has received no loan proceeds under this agreement, and RJC is in default of its funding obligations thereunder.
To guarantee RJC’s obligation in connection with the RJC Fundings as required under the Amended NPA, GGE entered into a Share Pledge Agreement with the Company, dated May 12, 2016 (the “GGE Pledge Agreement”), pursuant to which GGE agreed to pledge an aggregate of 10,000 shares of the Company’s Series A Convertible Preferred Stock held by GGE (convertible into 1,000,000 shares of Company common stock), which pledged shares are subject to automatic cancellation and forfeiture based on a schedule set forth in the GGE Share Pledge Agreement, in the event RJC fails to meet each of its RJC Funding obligations pursuant to the Amended NPA. To date, RJC has not met its RJC Funding obligations under the Amended NPA and the Company is entitled to cancel and forfeit the entire 10,000 pledged shares of the Company’s Series A Convertible Preferred Stock held by GGE pursuant to the terms of the GGE Pledge Agreement, which determination to cancel shares has not been made, and which shares have not been cancelled, as of the date of this filing.
As additional consideration for the entry into the Amended NPA, the Company granted to BHLN and BBLN, warrants exercisable for an aggregate of 596,280 shares of common stock of the Company (the “Investor Warrants”). The warrants have a 3-year term, are transferrable, and are exercisable on a cashless basis at any time at $2.50 per share (as amended). The Investor Warrants include a beneficial ownership limitation that prohibits the exercise of the Investor Warrants to the extent such exercise would result in the holder, together with its affiliates, holding more than 9.99% of the Company’s outstanding voting stock (the “Blocker Provision”). The estimated fair value of the Investor Warrants issued is approximately $707,000 based on the Black-Scholes option pricing model. The relative fair value allocated to the Tranche A Notes and recorded as debt discount was $636,000.
Other than the Investor Warrants, no additional warrants exercisable for common stock of the Company are due, owing, or shall be granted to the Lenders pursuant to the Senior Notes, as amended. In addition, warrants exercisable for an aggregate of 34,912 shares of the Company’s common stock at an exercise price of $15.00 per share and warrants exercisable for an aggregate of 120,101 shares of the Company’s common stock at an exercise price of $7.50 per share previously granted by the Company to certain of the Lenders on September 10, 2015 in connection with prior interest payment deferrals have been amended and restated to provide that all such warrants are exercisable on a cashless basis and to include a Blocker Provision (the “Amended and Restated Warrants”).
Additionally, the Company also agreed to (a) provide to the Agent and the Investors a monthly projected general and administrative expense report (the “Projected G&A”) and a monthly comparison report of the Projected G&A provided for the preceding month, with an explanation of any variances, provided that in no event shall such variances exceed $150,000, and (b) pay to the Agent within 2 business days following the end of each calendar month all of the Company’s oil and gas revenue received by the Company during such month (the “Net Revenue Sweep”), less (i) lease operating expenses, (ii) interest payments due to Investors under the New Senior Notes, (iii) general and administrative expenses not to exceed $150,000 per month unless preapproved by the Agent (the “G&A Cap”), and (iv) preapproved extraordinary expenses (together the “Monthly Net Revenues”). Amounts paid to the Agent through the Net Revenue Sweep are applied first to the repayment of principal and interest due under the Tranche A Notes until such notes are paid in full and then to the repayment of principal and interest amounts due under the Tranche B Notes. As of June 30, 2017, the Company has paid $682,000 of principal under the Net Revenue Sweep, of which $30,000 was paid during the current six month period. The amount of interest deferred under the Tranche A and Tranche B Notes as of June 30, 2017 and December 31, 2016, equaled $2,223,000 and $1,266,000, respectively, and was accounted for on the balance sheet under long-term accrued expenses and accrued expenses - related party.
The amounts outstanding under the New Senior Notes are secured by a first priority security interest in all of the Company’s and its subsidiaries’ assets, property, real property, intellectual property, securities and proceeds therefrom, granted in favor of the Agent for the benefit of the Lenders, pursuant to a Security Agreement and a Patent Security Agreement, each entered into as of March 7, 2014, as amended on May 12, 2016 (the “Amended Security Agreement” and “Amended Patent Agreement,” respectively). Additionally, the Agent, for the benefit of the Lenders, was granted a mortgage and security interest in all of the Company’s and its subsidiaries real property as located in the State of Colorado and the State of Texas pursuant to (i) a Leasehold Deed of Trust, Fixture Filing, Assignment of Rents and Leases, and Security Agreements, dated March 7, 2014, as amended May 12, 2016, filed in Weld County and Morgan County, Colorado; and (ii) a Mortgage, Deed of Trust, Security Agreement, Financing Statement and Assignment of Production filed in Matagorda County, Texas (collectively, the “Amended Mortgages”).
Other than as described above, the terms of the Amended NPA (including the covenants and obligations thereunder) are substantially the same as the March 2014 Notes Purchase Agreement described above, and the terms of the Tranche A Notes and Tranche B Notes (including the events of default, interest rates and conditions associated therewith) are substantially the same as the Senior Notes.
All debt discount amounts are amortized using the effective interest rate method. The total amount of the remaining debt discount reflected on the accompanying balance sheet as of June 30, 2017 and December 31, 2016 was $5,345,000 and $6,988,000, respectively. Amortization of debt discount and total interest expense for the initial notes (New Senior Notes – Trance A and Tranche B) was $1,643,000 and $3,278,000, respectively, for the six months ended June 30, 2017 and $3,756,000 and $3,646,000, respectively, for the six months ended June 30, 2016.
Amortization of debt discount and total interest expense for the initial notes (New Senior Notes – Tranche B) was $812,000 and $1,674,000, respectively, for the three months ended June 30, 2017 and was $1,562,000 and $2,169,000, respectively, for the three months ended June 30, 2016.
Junior Debt Restructuring
On May 12, 2016, the Company entered into an Amendment No. 2 to Note and Security Agreement with RJC (the “Second Amendment”). The Company and RJC agreed to amend the RJC Junior Note to (i) capitalize all accrued and unpaid interest under the RJC Junior Note as of May 12, 2016, and add it to the note principal, making the outstanding principal amount of the RJC Junior Note as of May 12, 2016 equal to $9,379,000, (ii) extend the maturity date (“Termination Date”) from December 31, 2017 to July 11, 2019, (iii) provide that all future interest accruing under the RJC Junior Note is deferred until payable on the Termination Date, with all future interest amounts deferred being added to the principal on a monthly basis, and (iv) subordinate the RJC Junior Note to the New Senior Notes.
Bridge Note Financing
As of June 30, 2017, the Company had Bridge Notes with an aggregate principal amount of $475,000 remaining outstanding, plus accrued interest of $202,000 and additional payment-in-kind (“PIK”) of $48,000. The aggregate principal and accrued and unpaid interest and PIK amounts are available for conversion into common stock pursuant to the terms of the Bridge Notes into common stock of the Company, subject to no more than 19.99% of the Company’s outstanding common stock on the date the Second Amended Notes were entered into. Upon a conversion, the applicable holder shall receive that number of shares of common stock as is determined by dividing the Conversion Amount by a conversion price as follows:
Additionally, each Amended Bridge Investor entered into a Subordination and Intercreditor Agreement in favor of the Agent, subordinating and deferring the repayment of the Bridge Notes until full repayment of certain senior notes. The Subordination and Intercreditor Agreements also prohibit the Company from repaying the Bridge Notes until certain senior notes have been paid in full. The interest expense related to these notes for the three and six months ended June 30 , 2017 and 2016 was $14,000 compared to $14,000 and $28,000 compared to $28,000, respectively.
The unamortized debt premium on the Convertible Bridge Notes as of June 30, 2017 and December 31, 2016, was $113,000.
MIE Jurassic Energy Corporation
On February 14, 2013, PEDCO entered into a Secured Subordinated Promissory Note with MIE Jurassic Energy Corp. (“MIEJ”), which was amended on March 25, 2013 and July 9, 2013 (the “MIEJ Note”, as amended through December 31, 2014) with MIEJ.
In February 2015, the Company and PEDCO entered into a Settlement Agreement with MIEJ and issued a new promissory note in the amount of $4.925 million to MIEJ (the “NEW MIEJ Note”). The Settlement Agreement related to the February 2015 disposition of the Company’s interest in Condor Energy Technology, LLC, a joint venture previously owned 20% by the Company and 80% by MIEJ. As of June 30, 2017, the amount outstanding under the New MIEJ Note was $4,925,000.
The New MIEJ Note has an interest rate of 10.0%, with no interest due until maturity, is secured by all of the Company’s assets, and is subordinated to the Senior Notes. MIEJ also agreed to subordinate its note up to an additional $60 million of new senior lending, with any portion of new senior lending in excess of this amount required to be paid first to MIEJ until the New MIEJ Note is paid in full. Further, for every $20 million in new senior lending the Company raises, MIEJ is required to be paid all interest and fees accrued on the New MIEJ Note through such date. The New MIEJ Note was due and payable on March 8, 2017, subject to automatic extensions upon the occurrence of a Long Term Financing (defined below), which as described below has occurred to date.
On a one-time basis, the Secured Promissory Notes may be refinanced by a new loan (“Long-Term Financing”) by one or more third party replacement lenders (“Replacement Lenders”), and in such event the Company shall undertake commercially reasonable best efforts to cause the Replacement Lenders to simultaneously refinance both the Senior Notes and the New MIEJ Note as part of such Long-Term Financing. If the Replacement Lenders are unable or unwilling to include the New MIEJ Note in such financing, then the Long-Term Financing may proceed without including the New MIEJ Note, and the New MIEJ Note shall remain in place and shall be automatically subordinated, without further consent of MIEJ, to such Long-Term Financing. Furthermore, upon the occurrence of a Long-Term Financing, the maturity of the New MIEJ Note is automatically extended to the same maturity date of the Long-Term Financing, but to no later than March 8, 2020. Additionally, in connection with a contemplated Long-Term Financing:
In the event the Senior Notes are not refinanced, restructured or extended by the Lenders, the maturity of both the New MIEJ Note and the Senior Notes may be extended to no later than March 8, 2019, without requiring the consent of MIEJ. However, (i) any such maturity extension of the New MIEJ Note will give MIEJ the right to convert the note into our common stock as described above, commencing on March 8, 2017, and (ii) such extension agreement must provide that MIEJ is paid all interest and fees accrued on the New MIEJ Note as of March 8, 2018. The New MIEJ Note may be prepaid any time without penalty.
As a result of the Company’s May 2016 senior debt restructuring pursuant to the Amended NPA (as described above under “Note Purchase Agreement and Sale of Secured Promissory Notes” – “2016 Senior Note Restructuring”), the maturity date of the New MIEJ Note has automatically been extended to March 8, 2019, and as a result of the Company’s shareholders approving the conversion terms of the MIEJ Note at the Company’s annual shareholder meeting held on December 28, 2016, MIEJ has had the Right of Conversion (described above) since March 8, 2017.
The interest expense related to this note for the three and six months ended June 30, 2017 and 2016 was $123,000 compared to $124,000 and $246,000 compared to $248,000, respectively, with the total cumulative interest equal to $1,231,000 through June 30, 2017.
For financial reporting purposes, MIEJ was considered a related party for all periods presented prior to the MIEJ Settlement Agreement signed in February 2015. After that date, MIEJ is no longer considered a related party.
Related Party Financings
Subordinated Note Payable Assumed
In 2015, the Company assumed approximately $8.35 million of subordinated note payable from GGE in the acquisition of the GGE Acquired Assets (the “RJC Junior Note”). The amount outstanding on the RJC Junior Note as of June 30, 2017 and December 31, 2016 was $10,803,000 and $10,173,000, respectively. The lender under the RJC Junior Note is RJC, which is one of the lenders under the Senior Notes and is an affiliate of GGE. The note was originally due and payable on December 31, 2017, but has been extended to July 11, 2019 in connection with the May 2016 restructuring as described above. The assumed note payable is subordinate to the Senior Notes, as well as any future secured indebtedness from a lender with an aggregate principal amount of at least $20,000,000. Should the Company repay the Senior Notes or replace them with secured indebtedness from a lender with an aggregate principal amount of at least $20,000,000, RJC agreed to further amend the subordinated note payable to adjust the frequency of interest payments or to eliminate the payments and replace them with a single payment of the accrued interest to be paid at maturity.
The interest expense related to this note for the three and six months ended June 30, 2017 and 2016 was $322,000 compared to $285,000 and $630,000 compared to $561,000, respectively.
2016 RJC Subordinated Note Deferrals
On January 29, 2016 and March 7, 2016, the Company entered into agreements with RJC to defer until maturity the payment of interest and principal due under the RJC Junior Note through March 31, 2016, and reduce the interest rate to 12% per annum effective January 31, 2016.
The deferral period was further extended on May 12, 2016, on which date the Company entered into an Amendment No. 2 to Note and Security Agreement with RJC (the “Second Amendment”). The Company and RJC agreed to amend the RJC Junior Note to (i) capitalize all accrued and unpaid interest under the RJC Junior Note as of May 12, 2016, and add it to the note principal, making the outstanding principal amount of the RJC Junior Note as of June 12, 2016 equal to $9,379,432, (ii) extend the maturity date from December 31, 2017 to July 11, 2019, (iii) provide that all future interest accruing under the RJC Junior Note is deferred until payable on the maturity date, with all future interest amounts deferred being added to the principal on a monthly basis, and (iv) subordinate the RJC Junior Note to the New Senior Notes. The warrants previously granted to RJC on September 10, 2015 were also amended to provide that such warrants are exercisable on a cashless basis and to include a Blocker Provision (as defined above).
As of June 30, 2017 and December 31, 2016, interest deferred and capitalized since May 12, 2016 under Amendment No. 2 to the Note amounted to $1,424,000 and $794,000, respectively, and amounted to total deferred interest of $630,000 since January 1, 2017. The outstanding principal amount of the RJC Junior Note as of June 30, 2017 and December 31, 2016 was equal to $10,803,000 and $10,173,000, respectively.
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9. COMMITMENTS AND CONTINGENCIES |
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Commitments and Contingencies Disclosure [Abstract] | |
COMMITMENTS AND CONTINGENCIES | Office Lease
In June 2017, the Company entered into a second lease addendum to the original lease agreement signed in July 2012 and the first lease addendum signed in May 2016, as amended, which extends the term of the lease by an additional one year, now ending in July 2018, for its corporate office space located in Danville, California. The obligation under this one-year lease extension for the remainder of the lease through July 2018 is $58,000.
In September 2014, the Company entered into a lease agreement for office space located in Houston, Texas, with a term of five years ending on March 1, 2020, which location served as the Company’s operations office. Effective April 1, 2016, the Company terminated this lease agreement and issued the landlord 70,000 shares of restricted common stock valued at $161,000, with no further obligations due thereunder.
Leasehold Drilling Commitments
The Company’s oil and gas leasehold acreage is subject to expiration of leases if the Company does not drill and hold such acreage by production or otherwise exercises options to extend such leases, if available, in exchange for payment of additional cash consideration. In the D-J Basin Asset, 6 net acres are due to expire during the six months remaining in 2017 (409 net acres did expire during the six months ended June 30, 2017), 561 net acres expire in 2018, 129 net acres expire in 2019, 1,288 net acres expire thereafter (net to our direct ownership interest only). The Company plans to hold significantly all of this acreage through a program of drilling and completing producing wells. If the Company is not able to drill and complete a well before lease expiration, the Company may seek to extend leases where able. As of June 30, 2017, the Company had fully impaired its unproved leasehold costs based on management’s revised re-leasing program.
Other Commitments
On December 18, 2015, a complaint was filed against Red Hawk, our wholly-owned subsidiary, in the District Court, County of Weld, State of Colorado (Case Number: 2015CV31079) (the “Court”), pursuant to which Liberty Oilfield Services, LLC (“Liberty”) made various claims against Red Hawk in connection with certain completion services provided by Liberty to Red Hawk in November and December 2014, and accrued in accounts payable as of December 31, 2014. The complaint alleges causes of action for foreclosure of lien, breach of contract, quantum meruit and account stated, and seeks payment of amounts allegedly owed, pre- and post-judgment interest, attorneys’ fees and court costs in connection with Red Hawk’s alleged failure to pay Liberty approximately $2.9 million in fees due for completion services provided by Liberty. On May 12, 2016, the Company and Liberty entered into a settlement agreement, pursuant to which the Company paid to Liberty $750,000 and issued 245,000 fully-vested shares of the Company’s restricted common stock, valued at $588,000, based on the market price on the grant date, as full settlement of all amounts due for the services previously rendered, for which the Company owed approximately $2.6 million. As a result of the settlement, the Company recognized a gain on settlement of payables of $1,282,000 during the year ended December 31, 2016.
Although we may, from time to time, be involved in litigation and claims arising out of our operations in the normal course of business, we are not currently a party to any material legal proceeding. In addition, we are not aware of any material legal or governmental proceedings against us, or contemplated to be brought against us.
As part of its regular operations, the Company may become party to various pending or threatened claims, lawsuits and administrative proceedings seeking damages or other remedies concerning its commercial operations, products, employees and other matters.
Although the Company provides no assurance about the outcome of these or any other pending legal and administrative proceedings and the effect such outcomes may have on the Company, the Company believes that any ultimate liability resulting from the outcome of such proceedings, to the extent not otherwise provided for or covered by insurance, will not have a material adverse effect on the Company’s financial condition or results of operations.
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10. SHAREHOLDERS' DEFICIT |
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Equity [Abstract] | ||||||||||||||||
SHAREHOLDERS' DEFICIT | PREFERRED STOCK
At June 30, 2017, the Company was authorized to issue 100,000,000 shares of preferred stock with a par value of $0.001 per share, of which 25,000,000 shares have been designated “Series A” preferred stock.
On February 23, 2015, the Company issued 66,625 Series A Preferred shares to GGE as part of the consideration paid for the GGE Acquired Assets. The grant date fair value of the Series A Preferred stock was $28,402,000, based on a calculation using a binomial lattice option pricing model. See Note 13 below.
The 66,625 shares of Series A Preferred stock issued to GGE were originally contingently redeemable in 4 tranches as follows: (i) 15,000 shares in Tranche One; (ii) 15,000 shares in Tranche Two; (iii) 11,625 shares in Tranche Three; and (iv) 25,000 shares in Tranche Four.
In addition, upon the original issuance of the 66,625 shares of Series A Preferred stock issued to GGE, the Series A preferred stock had the following features:
However, following the October 7, 2015 approval of the Company shareholders of the issuance of shares of common stock upon the conversion of the Series A Preferred stock, the Series A Preferred features have been modified as follows:
GGE was also subject to a lock-up provision that prohibited it from selling the shares of common stock through the public markets for less than $10 per share (on an as-converted to common stock basis) until February 23, 2016, and subject to a provision which prohibits GGE from converting shares of Series A Preferred stock if upon such conversion it would beneficially own more than 9.99% of our outstanding common stock or voting stock, subject to waiver by the Company.
On November 23, 2015, the Company lost the right to redeem any of the Series A Preferred and the holder also lost the right to force any redemption because, pursuant to the Series A Certificate of Designations, the Company did not repurchase any shares within nine months of the initial Series A issuance. Accordingly, the Series A Preferred is no longer redeemable.
As of June 30, 2017 and December 31, 2016, there were 66,625 shares of the Company’s Series A Preferred outstanding, 10,000 shares of which are now subject to cancellation and forfeiture as described further in the Notes above due to RJC’s failure to meet its RJC Funding obligations under the Amended NPA.
COMMON STOCK
At June 30, 2017, the Company was authorized to issue 200,000,000 shares of its common stock with a par value of $0.001 per share.
The Company completed a 1-for-10 reverse split of its outstanding common stock, which took effect as of market close on April 7, 2017. Before the split, the Company had approximately 54.9 million shares of common stock issued and outstanding, and following the reverse split, the Company now has approximately 5.49 million shares of common stock issued and outstanding (subject to adjustment for settlement of fractional shares which were rounded up to the nearest whole share). All outstanding options, warrants, preferred stock and other securities convertible into the Company's common stock have been adjusted as a result of the reverse stock split as required by the terms of such securities with a proportional increase in the exercise price.
During the six months ended June 30, 2017, the Company issued a total of 550,335 shares of common stock under the At Market Issuance Sales Agreement with National Securities Corporation effective September 29, 2016 for gross proceeds of $587,000 and proceeds net of all issuance costs equal to $495,000.
As of June 30, 2017, there were 6,044,729 shares of common stock outstanding.
Stock-based compensation expense recorded related to the vesting of restricted stock for the three and six months ended June 30, 2017 and 2016 was $214,000 compared to $438,000 and $462,000 compared to $809,000, respectively. The remaining unamortized stock-based compensation expense at June 30, 2017 related to restricted stock was $139,000.
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11. STOCK OPTIONS AND WARRANTS |
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STOCK OPTIONS AND WARRANTS | Blast 2003 Stock Option Plan and 2009 Stock Incentive Plan
Prior to June 2005, we were known as Blast Energy Services, Inc. (“Blast”). Under Blast’s 2003 Stock Option Plan and 2009 Stock Incentive Plan, options to acquire 343 shares of common stock were granted and remained outstanding and exercisable as of June 30, 2017 and December 31, 2016. No new options were issued under these plans in 2017 or 2016.
2012 Incentive Plan
On July 27, 2012, the shareholders of the Company approved the 2012 Equity Incentive Plan (the “2012 Incentive Plan”), which was previously approved by the Board of Directors on June 27, 2012, and authorizes the issuance of various forms of stock-based awards, including incentive or non-qualified options, restricted stock awards, performance shares and other securities as described in greater detail in the 2012 Incentive Plan, to the Company’s employees, officers, directors and consultants. The 2012 Incentive Plan was amended on June 27, 2014, October 7, 2015 and December 28, 2016 to increase by 500,000, 300,000 and 500,000, respectively, the number of shares of common stock reserved for issuance under the Plan. A total of 1,500,000 shares of common stock are eligible to be issued under the 2012 Incentive Plan as of June 30, 2017 and December 31, 2016, of which 1,102,099 shares have been issued as restricted stock, 396,700 shares are subject to issuance upon exercise of issued and outstanding options, and 1,201 remain available for future issuance as of June 30, 2017 and December 31, 2016.
PEDCO 2012 Equity Incentive Plan
As a result of the July 27, 2012 merger by and between the Company, Blast Acquisition Corp., a wholly-owned Nevada subsidiary of the Company (“MergerCo”), and PEDCO pursuant to which MergerCo was merged with and into PEDCO, with PEDCO continuing as the surviving entity and becoming a wholly-owned subsidiary of the Company, in a transaction structured to qualify as a tax-free reorganization (the “Merger”), the Company assumed the PEDCO 2012 Equity Incentive Plan (the “PEDCO Incentive Plan”), which was adopted by PEDCO on February 9, 2012. The PEDCO Incentive Plan authorized PEDCO to issue an aggregate of 100,000 shares of common stock in the form of restricted shares, incentive stock options, non-qualified stock options, share appreciation rights, performance shares, and performance units under the PEDCO Incentive Plan. As of June 30, 2017 and December 31, 2016, options to purchase an aggregate of 31,014 shares of the Company’s common stock and 66,583 shares of the Company’s restricted common stock have been granted under this plan (all of which were granted by PEDCO prior to the closing of the merger with the Company, with such grants being assumed by the Company and remaining subject to the PEDCO Incentive Plan following the consummation of the merger). The Company does not plan to grant any additional awards under the PEDCO Incentive Plan.
Options
The Company did not grant any options during the six-month period ending June 30, 2017.
During the three and six months ended June 30, 2017 and 2016, the Company recognized stock option expense of $27,000 compared to $125,000 and $55,000 compared to $256,000, respectively. The remaining amount of unamortized stock options expense at June 30, 2017, was $17,000.
The intrinsic value of outstanding and exercisable options at June 30, 2017 was $-0-.
The intrinsic value of outstanding and exercisable options at December 31, 2016 was $-0-.
Option activity during the six months ended June 30, 2017 was:
Warrants
During the three and six months ended June 30, 2017 and 2016, the Company recognized warrant expense of $-0-. The remaining amount of unrecognized warrant expense at June 30, 2017 was $-0-.
The intrinsic value of outstanding as well as exercisable warrants at June 30, 2017 and December 31, 2016 was $-0- and $-0-, respectively.
Warrant activity during the six months ended June 30, 2017 was:
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12. RELATED PARTY TRANSACTIONS |
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RELATED PARTY TRANSACTIONS | Note Amendments and Warrant Issuances to RJC
See Note 8 above for a discussion of certain amendments to the Senior Note and RJC Junior Note held by RJC.
See Note 8 above for a discussion of certain warrants issued to RJC by the Company in connection with the amendment of the Senior Note and RJC Junior Note held by RJC.
GGE Acquisition
As a result of the 66,625 restricted shares of the Company’s Series A Convertible Preferred Stock issued to GGE which can be converted into shares of the Company’s common stock on a 100:1 basis as described below in greater detail, and the appointment by GGE of a representative to the Company’s Board of Directors, GGE became a related party to the Company in 2015. The following table reflects the related party amounts for GGE included in the June 30, 2017 balance sheet (in thousands):
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13. FAIR VALUE OF FINANCIAL INSTRUMENTS |
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FAIR VALUE OF FINANCIAL INSTRUMENTS | As defined in our accounting policy on the fair value of financial instruments, financial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels.
The following table sets forth by level within the fair value hierarchy our financial instruments that were accounted for at fair value as of June 30, 2017 (in thousands):
The Company believes there is no active market or significant other market data for the Series A Preferred as it is held by a limited number of closely held entities, therefore the Company has determined it should use Level 3 inputs.
The Series A Convertible Preferred was valued using the binomial lattice model of which the significant assumptions were expected term and expected volatility. The binomial lattice model used a probablistic approach in which the Company assigned percentages to each scenario based on the chance of repayment. The percentages used were as follows: the non-repayment scenario was assigned a 25% probability and the repayment scenario was assigned a 75% probability.
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14. INCOME TAXES |
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Jun. 30, 2017 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Income Tax Disclosure [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
INCOME TAXES | Due to the Company’s net losses, there was no provision for income taxes for the six months ended June 30, 2017 and 2016.
The difference between the income tax expense of zero shown in the statement of operations and pre-tax book net loss times the federal statutory rate of 34% is principally due to the increase in the valuation allowance.
Deferred income tax assets as of June 30, 2017 and December 31, 2016 are as follows (in thousands):
In assessing the realization of deferred tax assets, management considers whether it is more likely than not that some portion or all of deferred assets will not be realized. The ultimate realization of the deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible.
Based on the available objective evidence, management believes it is more likely than not that the net deferred tax assets will not be fully realizable. Accordingly, management has applied a full valuation allowance against its net deferred tax assets at June 30, 2017. The net change in the total valuation allowance from December 31, 2016 to June 30, 2017 was a decrease of $3,813,000.
The Company’s policy is to recognize interest and penalties accrued on any unrecognized tax benefits as a component of income tax expense. As of June 30, 2017, the Company did not have any significant uncertain tax positions or unrecognized tax benefits. The Company did not have associated accrued interest or penalties, nor were there any interest expense or penalties recognized during the period from February 9, 2011 (Inception) through June 30, 2017.
As of June 30, 2017, the Company had net operating loss carryforwards (“NOLs”) of approximately $82,290,000 and $49,922,000 (subject to limitations) for federal and state tax purposes. If not utilized, these losses will begin to expire beginning in 2033 and 2023, respectively, for both federal and state purposes.
Utilization of NOL and tax credit carryforwards may be subject to a substantial annual limitation due to ownership change limitations that may have occurred or that could occur in the future, as required by the Internal Revenue Code (the “Code”), as amended, as well as similar state provisions. In general, an “ownership change” as defined by the Code results from a transaction or series of transactions over a three-year period resulting in an ownership change of more than 50% of the outstanding stock of a company by certain stockholders or public groups.
The Company currently has tax returns open for examination by the Internal Revenue Service for all years since 2009.
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15. SUBSEQUENT EVENTS |
6 Months Ended |
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Jun. 30, 2017 | |
Subsequent Events [Abstract] | |
SUBSEQUENT EVENTS | On July 24, 2017, the Company sold 40,000 shares of common stock under the At Market Issuance Sales Agreement with National Securities Corporation effective September 29, 2016, at a purchase price of $0.90 per share, for gross proceeds of $36,000, to which an underwriter’s fee of 3.0% was applied.
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3. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies) |
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Jun. 30, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Accounting Policies [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Basis of Presentation and Principles of Consolidation | The consolidated financial statements herein have been prepared in accordance with GAAP and include the accounts of the Company and those of its wholly and partially-owned subsidiaries as follows: (i) Blast AFJ, Inc., a Delaware corporation; (ii) Pacific Energy Development Corp. (“PEDCO”), a Nevada corporation; (iii) Pacific Energy & Rare Earth Limited, a Hong Kong company (which is currently in the process of being dissolved); (iv) Blackhawk Energy Limited, a British Virgin Islands company (which is currently in the process of being dissolved); (v) White Hawk Petroleum, LLC, a Nevada limited liability company (dissolved on November 30, 2016); (vi) Red Hawk Petroleum, LLC, a Nevada limited liability company; (vii) Pacific Energy Development MSL, LLC (owned 50% by us) (which was dissolved in September 2016) and is included in our consolidated results for the periods prior to its dissolution (“PEDCO MSL”); (viii) PEDEVCO Acquisition Subsidiary, Inc., a Texas corporation which was formed on May 21, 2015 in connection with the planned reorganization transaction with Dome Energy, Inc. (“Dome Energy”), which was subsequently terminated (which was dissolved in April 2016); and (ix) White Hawk Energy, LLC, a Delaware limited liability company, formed on January 4, 2016 in connection with the contemplated reorganization transaction with GOM Holdings, LLC (“GOM”), which reorganization transaction has since been terminated. All significant intercompany accounts and transactions have been eliminated. |
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Use of Estimates in Financial Statement Preparation | The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, as well as certain financial statement disclosures. While management believes that the estimates and assumptions used in the preparation of the financial statements are appropriate, actual results could differ from these estimates. Significant estimates generally include those with respect to the amount of recoverable oil and gas reserves, the fair value of financial instruments, oil and gas depletion, asset retirement obligations, and stock-based compensation.
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Cash and Cash Equivalents | The Company considers all highly liquid investments with original maturities of three months or less to be cash equivalents. As of June 30, 2017, and December 31, 2016, cash equivalents consisted of money market funds and cash on deposit.
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Concentrations of Credit Risk | Financial instruments which potentially subject the Company to concentrations of credit risk include cash deposits placed with financial institutions. The Company maintains its cash in bank accounts which, at times, may exceed federally insured limits as guaranteed by the Federal Deposit Insurance Corporation (“FDIC”). At June 30, 2017, approximately $391,000 of the Company’s cash balances were uninsured. The Company has not experienced any losses on such accounts.
Sales to one customer comprised 56% of the Company’s total oil and gas revenues for the six months ended June 30, 2017. Sales to one customer comprised 58% of the Company’s total oil and gas revenues for the six months ended June 30, 2016. The Company believes that, in the event that its primary customers are unable or unwilling to continue to purchase the Company’s production, there are a substantial number of alternative buyers for its production at comparable prices.
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Accounts Receivable | Accounts receivable typically consist of oil and gas receivables. The Company has classified these as short-term assets in the balance sheet because the Company expects repayment or recovery within the next 12 months. The Company evaluates these accounts receivable for collectability considering the results of operations of these related entities and, when necessary, records allowances for expected unrecoverable amounts. To date, no allowances have been recorded. Included in accounts receivable - oil and gas is $-0- related to receivables from joint interest owners. |
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Bad Debt Expense | The Company’s ability to collect outstanding receivables is critical to its operating performance and cash flows. Accounts receivable are stated at an amount management expects to collect from outstanding balances. The Company extends credit in the normal course of business. The Company regularly reviews outstanding receivables and when the Company determines that a party may not be able to make required payments, a charge to bad debt expense in the period of determination is made. Though the Company’s bad debts have not historically been significant, the Company could experience increased bad debt expense should a financial downturn occur.
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Equipment | Equipment is stated at cost less accumulated depreciation and amortization. Maintenance and repairs are charged to expense as incurred. Renewals and betterments which extend the life or improve existing equipment are capitalized. Upon disposition or retirement of equipment, the cost and related accumulated depreciation are removed and any resulting gain or loss is reflected in operations. Depreciation is provided using the straight-line method over the estimated useful lives of the assets, which are 3 to 10 years.
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Oil and Gas Properties, Successful Efforts Method | The successful efforts method of accounting is used for oil and gas exploration and production activities. Under this method, all costs for development wells, support equipment and facilities, and proved mineral interests in oil and gas properties are capitalized. Geological and geophysical costs are expensed when incurred. Costs of exploratory wells are capitalized as exploration and evaluation assets pending determination of whether the wells find proved oil and gas reserves. Proved oil and gas reserves are the estimated quantities of crude oil and natural gas which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions, (i.e., prices and costs as of the date the estimate is made). Prices include consideration of changes in existing prices provided only by contractual arrangements, but not on escalations based upon future conditions.
Exploratory wells in areas not requiring major capital expenditures are evaluated for economic viability within one year of completion of drilling. The related well costs are expensed as dry holes if it is determined that such economic viability is not attained. Otherwise, the related well costs are reclassified to oil and gas properties and subject to impairment review. For exploratory wells that are found to have economically viable reserves in areas where major capital expenditure will be required before production can commence, the related well costs remain capitalized only if additional drilling is under way or firmly planned. Otherwise the related well costs are expensed as dry holes.
Exploration and evaluation expenditures incurred subsequent to the acquisition of an exploration asset in a business combination are accounted for in accordance with the policy outlined above.
Depreciation, depletion and amortization of capitalized oil and gas properties is calculated on a field by field basis using the unit of production method. Lease acquisition costs are amortized over the total estimated proved developed and undeveloped reserves and all other capitalized costs are amortized over proved developed reserves.
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Impairment of Long-Lived Assets | The Company reviews the carrying value of its long-lived assets annually or whenever events or changes in circumstances indicate that the historical cost-carrying value of an asset may no longer be appropriate. The Company assesses recoverability of the carrying value of the asset by estimating the future net undiscounted cash flows expected to result from the asset, including eventual disposition. If the future net undiscounted cash flows are less than the carrying value of the asset, an impairment loss is recorded equal to the difference between the asset’s carrying value and estimated fair value.
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Asset Retirement Obligations | If a reasonable estimate of the fair value of an obligation to perform site reclamation, dismantle facilities or plug and abandon wells can be made, the Company will record a liability (an asset retirement obligation or “ARO”) on its consolidated balance sheet and capitalize the present value of the asset retirement cost in oil and gas properties in the period in which the retirement obligation is incurred. In general, the amount of an ARO and the costs capitalized will be equal to the estimated future cost to satisfy the abandonment obligation assuming the normal operation of the asset, using current prices that are escalated by an assumed inflation factor up to the estimated settlement date, which is then discounted back to the date that the abandonment obligation was incurred using an assumed cost of funds for the Company. After recording these amounts, the ARO will be accreted to its future estimated value using the same assumed cost of funds and the capitalized costs are depreciated on a unit-of-production basis over the estimated proved developed reserves. Both the accretion and the depreciation will be included in depreciation, depletion and amortization expense on our consolidated statements of operations.
The following table describes changes in our asset retirement obligations during the six months ended June 30, 2017 and 2016 (in thousands):
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Revenue Recognition | All revenue is recognized when persuasive evidence of an arrangement exists, the service or sale is complete, the price is fixed or determinable and collectability is reasonably assured. Revenue is derived from the sale of crude oil and natural gas. Revenue from crude oil and natural gas sales is recognized when the product is delivered to the purchaser and collectability is reasonably assured. The Company follows the “sales method” of accounting for oil and natural gas revenue, so it recognizes revenue on all natural gas or crude oil sold to purchasers, regardless of whether the sales are proportionate to its ownership in the property. A receivable or liability is recognized only to the extent that the Company has an imbalance on a specific property greater than its share of the expected remaining proved reserves. If collection is uncertain, revenue is recognized when cash is collected.
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Income Taxes | The Company utilizes the asset and liability method in accounting for income taxes. Under this method, deferred tax assets and liabilities are recognized for operating loss and tax credit carry-forwards and for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the year in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in the results of operations in the period that includes the enactment date. A valuation allowance is recorded to reduce the carrying amounts of deferred tax assets unless it is more likely than not that the value of such assets will be realized. |
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Stock-Based Compensation | The Company utilizes the Black-Scholes option pricing model to estimate the fair value of employee stock option awards at the date of grant, which requires the input of highly subjective assumptions, including expected volatility and expected life. Changes in these inputs and assumptions can materially affect the measure of estimated fair value of our share-based compensation. These assumptions are subjective and generally require significant analysis and judgment to develop. When estimating fair value, some of the assumptions will be based on, or determined from, external data and other assumptions may be derived from our historical experience with stock-based payment arrangements. The appropriate weight to place on historical experience is a matter of judgment, based on relevant facts and circumstances.
The Company estimates volatility by considering the historical stock volatility. The Company has opted to use the simplified method for estimating expected term, which is generally equal to the midpoint between the vesting period and the contractual term.
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Loss per Common Share | Basic loss per common share equals net loss divided by weighted average common shares outstanding during the period. Diluted loss per share includes the impact on dilution from all contingently issuable shares, including options, warrants and convertible securities. The common stock equivalents from contingent shares are determined by the treasury stock method. The Company incurred net losses for the six months ended June 30, 2017 and 2016, and therefore, basic and diluted loss per share for those periods are the same as all potential common equivalent shares would be anti-dilutive. The Company excluded 451,614 and 342,734 potentially issuable shares of common stock related to options, 1,248,045 and 1,376,609 potentially issuable shares of common stock related to warrants and 144,822 and 133,422 potentially issuable shares of common stock related to the conversion of Bridge Notes due to their anti-dilutive effect for the six months ended June 30, 2017 and 2016, respectively.
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Fair Value of Financial Instruments | The Company follows Fair Value Measurement (“ASC 820”), which clarifies fair value as an exit price, establishes a hierarchal disclosure framework for measuring fair value, and requires extended disclosures about fair value measurements. The provisions of ASC 820 apply to all financial assets and liabilities measured at fair value.
As defined in ASC 820, fair value, clarified as an exit price, represents the amount that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. As a result, fair value is a market-based approach that should be determined based on assumptions that market participants would use in pricing an asset or a liability.
As a basis for considering these assumptions, ASC 820 defines a three-tier value hierarchy that prioritizes the inputs used in the valuation methodologies in measuring fair value.
The fair value hierarchy also requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value.
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Recently Issued Accounting Pronouncements | In August 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-15, Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern. The new standard requires management to assess the company’s ability to continue as a going concern. Disclosures are required if there is substantial doubt as to the Company’s continuation as a going concern within one year after the issue date of financial statements. The standard provides guidance for making the assessment, including consideration of management’s plans which may alleviate doubt regarding the Company’s ability to continue as a going concern. ASU 2014-15 is effective for years ending after December 15, 2016. The Company adopted this standard for the six months ended June 30, 2017 and the year ended December 31, 2016, and management has concluded that there is substantial doubt as to the Company’s continuation as a going concern within one year after the issue date of the financial statements.
In May 2014, the FASB issued a comprehensive new revenue recognition standard that will supersede nearly all existing revenue recognition guidance under U.S. GAAP. The standard’s core principle (issued as ASU 2014-09 by the FASB), is that a company will recognize revenue when it transfers promised goods or services to customers in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services. These may include identifying performance obligations in the contract, estimating the amount of variable consideration to include in the transaction price and allocating the transaction price to each separate performance obligation. The new guidance must be adopted using either a full retrospective approach for all periods presented in the period of adoption or a modified retrospective approach. In August 2015, the FASB issued ASU No. 2015-14, which defers the effective date of ASU 2014-09 by one year, and would allow entities the option to early adopt the new revenue standard as of the original effective date. This ASU is effective for public reporting companies for interim and annual periods beginning after December 15, 2017. The Company has evaluated the adoption of the standard and due to the nature of the Company’s oil and gas revenue agreements method there will be no impact of the standard on its consolidated financial statements.
In April 2016, the FASB issued ASU No. 2016-10, “Revenue from Contracts with Customers: Identifying Performance Obligations and Licensing” (topic 606). In March 2016, the FASB issued ASU No. 2016-08, “Revenue from Contracts with Customers: Principal versus Agent Considerations (Reporting Revenue Gross verses Net)” (topic 606). These amendments provide additional clarification and implementation guidance on the previously issued ASU 2014-09, “Revenue from Contracts with Customers”. The amendments in ASU 2016-10 provide clarifying guidance on materiality of performance obligations; evaluating distinct performance obligations; treatment of shipping and handling costs; and determining whether an entity's promise to grant a license provides a customer with either a right to use an entity's intellectual property or a right to access an entity's intellectual property. The amendments in ASU 2016-08 clarify how an entity should identify the specified good or service for the principal versus agent evaluation and how it should apply the control principle to certain types of arrangements. The adoption of ASU 2016-10 and ASU 2016-08 is to coincide with an entity's adoption of ASU 2014-09, which would be adopted for interim and annual reporting periods beginning after December 15, 2017. The Company has evaluated the adoption of the standard and due to the nature of the Company’s oil and gas revenue agreements method there will be no impact of the standard on its consolidated financial statements.
In February 2016, the FASB issued ASU 2016-02, a new lease standard requiring lessees to recognize lease assets and lease liabilities for most leases classified as operating leases under previous U.S. GAAP. The guidance is effective for fiscal years beginning after December 15, 2018, with early adoption permitted. The Company will be required to use a modified retrospective approach for leases that exist or are entered into after the beginning of the earliest comparative period in the financial statements. The Company has evaluated the adoption of the standard and due to only one operating lease currently in place there will be minimal impact of the standard on its consolidated financial statements.
In April 2016, the FASB issued ASU No. 2016-09, “Compensation – Stock Compensation” (topic 718). The FASB issued this update to improve the accounting for employee share-based payments and affect all organizations that issue share-based payment awards to their employees. Several aspects of the accounting for share-based payment award transactions are simplified, including: (a) income tax consequences; (b) classification of awards as either equity or liabilities; and (c) classification on the statement of cash flows. The updated guidance is effective for annual periods beginning after December 15, 2016, including interim periods within those fiscal years. Early adoption of the update is permitted. The Company has evaluated the adoption of the standard and due to the nature of the Company’s employee share-based payments there will be no impact of the standard on its consolidated financial statements.
In August 2016, the FASB issued ASU 2016-15, “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments” (“ASU 2016-15”). ASU 2016-15 will make eight targeted changes to how cash receipts and cash payments are presented and classified in the statement of cash flows. ASU 2016-15 is effective for fiscal years beginning after December 15, 2017. The new standard will require adoption on a retrospective basis unless it is impracticable to apply, in which case it would be required to apply the amendments prospectively as of the earliest date practicable. The Company is currently in the process of evaluating the impact of ASU 2016-15 on its consolidated financial statements.
In November 2016, the FASB issued ASU 2016-18, “Statement of Cash Flows (Topic 230)”, requiring that the statement of cash flows explain the change in the total cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. This guidance is effective for fiscal years, and interim reporting periods therein, beginning after December 15, 2017 with early adoption permitted. The provisions of this guidance are to be applied using a retrospective approach which requires application of the guidance for all periods presented. The Company is currently evaluating the impact of the new standard.
The Company does not expect the adoption of any recently issued accounting pronouncements to have a significant impact on its financial position, results of operations, or cash flows.
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Subsequent Events | The Company has evaluated all transactions through the date the consolidated financial statements were issued for subsequent event disclosure consideration. |
3. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables) |
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Jun. 30, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Accounting Policies [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Asset retirement obligation |
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5. OIL AND GAS PROPERTIES (Tables) |
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Oil and Gas Property [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Oil and gas interests |
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Summary of Purchase Price |
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11. STOCK OPTIONS AND WARRANTS (Tables) |
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Schedule of Stock Option and Warrant Activity |
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Warrant | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Stock Option and Warrant Activity |
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12. RELATED PARTY TRANSACTIONS (Tables) |
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Jun. 30, 2017 | ||||||||||||||||||||||||||
Related Party Transactions [Abstract] | ||||||||||||||||||||||||||
Schedule Of Related Party Transactions |
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13. FAIR VALUE OF FINANCIAL INSTRUMENTS (Tables) |
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Jun. 30, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Fair Value Disclosures [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Level within the fair value hierarchy our financial instruments |
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14. INCOME TAXES (Tables) |
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Jun. 30, 2017 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Income Tax Disclosure [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred income taxes assets |
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3. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) - USD ($) $ in Thousands |
3 Months Ended | 6 Months Ended | |
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Mar. 31, 2016 |
Jun. 30, 2017 |
Jun. 30, 2016 |
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Summary Of Significant Accounting Policies Details | |||
Asset retirement obligation, beginning | $ 189 | $ 246 | $ 189 |
Accretion expense | 33 | 14 | |
Obligations incurred for acquisition | 0 | 19 | |
Changes in estimates | $ (9) | (1) | (9) |
Asset retirement obligation, ending | $ 278 | $ 213 |
3. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details Narrative) - shares |
6 Months Ended | |
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Jun. 30, 2017 |
Jun. 30, 2016 |
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Options | ||
Potentially issuable shares of common stock | 451,614 | 342,734 |
Warrant | ||
Potentially issuable shares of common stock | 1,248,045 | 1,376,609 |
Conversion of Bridge Notes | ||
Potentially issuable shares of common stock | 144,822 | 133,422 |
Customer 1 [Member] | ||
Percentage total oil and gas revenues | 56.00% | 58.00% |
5. OIL AND GAS PROPERTIES (Details 1) $ in Thousands |
6 Months Ended |
---|---|
Jun. 30, 2016
USD ($)
| |
Oil and Gas Property [Abstract] | |
Accounts receivable - oil and gas | $ 793 |
Oil and gas properties, subject to amortization | 3,587 |
Total assets | 4,380 |
Accounts payable | (4,361) |
Asset retirement obligations | (19) |
Total liabilities | (4,380) |
Net purchase price | $ 0 |
5. OIL AND GAS PROPERTIES (Details Narrative) - USD ($) $ in Thousands |
3 Months Ended | 6 Months Ended | ||
---|---|---|---|---|
Jun. 30, 2017 |
Jun. 30, 2016 |
Jun. 30, 2017 |
Jun. 30, 2016 |
|
Oil And Gas Properties Details Narrative | ||||
Depletion | $ 862 | $ 513 | $ 1,520 | $ 1,785 |
6. ACCOUNTS RECEIVABLE (Details Narrative) $ in Thousands |
Dec. 31, 2015
USD ($)
|
---|---|
Dome Energy [Member] | |
Accounts receivable | $ 406 |
8. NOTES PAYABLE (Details (Narrative) - USD ($) $ in Thousands |
3 Months Ended | 6 Months Ended | |||
---|---|---|---|---|---|
Jun. 30, 2017 |
Jun. 30, 2016 |
Jun. 30, 2017 |
Jun. 30, 2016 |
Dec. 31, 2016 |
|
Unamortized debt discount/premium | $ 6,988 | ||||
Tranche A Notes [Member] | |||||
Aggregate principal amount | $ 25,960 | $ 25,960 | |||
Deferred interest | 2,223 | 2,223 | 1,266 | ||
Tranche B Notes [Member] | |||||
Aggregate principal amount | 45,087 | 45,087 | |||
Deferred interest | 2,223 | 2,223 | 1,266 | ||
Bridge Note Financing [Member] | |||||
Aggregate principal amount | 475 | 475 | |||
Accrued Interest | 202 | 202 | |||
Additional PIK | 48 | 48 | |||
Unamortized debt discount/premium | 113 | 113 | 113 | ||
Interest expense | 14 | $ 14 | 28 | $ 28 | |
MIE Jurassic Energy Corporation [Member] | |||||
Aggregate principal amount | 4,925 | 4,925 | |||
Interest expense | 123 | 124 | 246 | 248 | |
Subordinated Note Payable Assumed [Member] | |||||
Aggregate principal amount | 10,803 | 10,803 | 10,173 | ||
Interest expense | 322,000 | $ 285,000 | 630,000 | $ 561,000 | |
2016 RJC Subordinated Note Deferrals [Member] | |||||
Aggregate principal amount | 10,803 | 10,803 | 10,173 | ||
Deferred interest | $ 1,424 | $ 1,424 | $ 794 |
9. COMMITMENTS AND CONTINGENCIES (Details Narrative) $ in Thousands |
12 Months Ended |
---|---|
Dec. 31, 2016
USD ($)
| |
Commitments And Contingencies Details Narrative | |
Gain on settlement of payables | $ 1,282 |
10. SHAREHOLDERS' DEFICIT (Details Narrative) - USD ($) $ / shares in Units, $ in Thousands |
3 Months Ended | 6 Months Ended | |||
---|---|---|---|---|---|
Jun. 30, 2017 |
Jun. 30, 2016 |
Jun. 30, 2017 |
Jun. 30, 2016 |
Dec. 31, 2016 |
|
Preferred stock shares authorized | 100,000,000 | 100,000,000 | 100,000,000 | ||
Preferred stock shares par value | $ 0.001 | $ 0.001 | $ 0.001 | ||
Preferred stock shares outstanding | 66,625 | 66,625 | 66,625 | ||
Common stock, par value | $ 0.001 | $ 0.001 | $ 0.001 | ||
Common stock, shares authorized | 200,000,000 | 200,000,000 | 200,000,000 | ||
Common stock, shares outstanding | 6,044,729 | 6,044,729 | 5,493,112 | ||
Stock compensation expense recorded related to restricted stock | $ 214 | $ 438 | $ 462 | $ 809 | |
Unamortized stock compensation expense | $ 139 | $ 139 | |||
Series A Preferred Stock | |||||
Preferred stock shares outstanding | 66,625 | 66,625 | 66,625 |
11. STOCK OPTIONS AND WARRANTS (Details Narrative) - USD ($) $ in Thousands |
3 Months Ended | 6 Months Ended | 12 Months Ended | ||
---|---|---|---|---|---|
Jun. 30, 2017 |
Jun. 30, 2016 |
Jun. 30, 2017 |
Jun. 30, 2016 |
Dec. 31, 2016 |
|
Option | |||||
Recognized stock option based compensation expense | $ 27 | $ 125 | $ 55 | $ 256 | |
Unamortized stock options expense | 17 | ||||
Intrinsic value of options outstanding | 0 | 0 | $ 0 | ||
Intrinsic value of options exercisable | 0 | 0 | 0 | ||
Warrant | |||||
Intrinsic value of options outstanding | 0 | 0 | 0 | ||
Intrinsic value of options exercisable | $ 0 | $ 0 | $ 0 | ||
Blast 2003 Stock Option Plan and 2009 Stock Incentive Plan | |||||
Common stock authorized to issue | 343 | 343 | |||
2012 Incentive Plan | |||||
Common stock authorized to issue | 1,500,000 | 1,500,000 | |||
Restricted stock issued | 1,102,099 | 1,102,099 | |||
Shares issued upon exercise | 396,700 | 396,700 | |||
Shares remain available for future issuancce | 1,201 | 1,201 | 1,201 |
12. RELATED PARTY TRANSACTIONS (Details) - USD ($) $ in Thousands |
Jun. 30, 2017 |
Jun. 30, 2016 |
---|---|---|
Total liabilities | $ 4,380 | |
GGE [Member] | ||
Accrued expenses | $ 1,201 | |
Long-term notes payable - Secured Promissory Notes, net of discount of $1,720,000 | 14,615 | |
Long-term notes payable-Secured Promissory Notes, net of discount | 10,803 | |
Total liabilities | $ 26,619 |
13. FAIR VALUE OF FINANCIAL INSTRUMENTS (Details) $ in Thousands |
Jun. 30, 2017
USD ($)
|
---|---|
Series A Convertible Preferred Stock | $ 28,402 |
Quoted Prices in Active Markets for Identical Assets (Level 1) | |
Series A Convertible Preferred Stock | 0 |
Significant Other Observable Inputs (Level 2) | |
Series A Convertible Preferred Stock | 0 |
Significant Unobservable Inputs (Level 3) | |
Series A Convertible Preferred Stock | $ 28,402 |
14. INCOME TAXES (Details) - USD ($) $ in Thousands |
Jun. 30, 2017 |
Dec. 31, 2016 |
---|---|---|
Deferred Tax Assets (Liabilities) | ||
Difference in depreciation, depletion, and capitalization methods - oil and natural gas properties | $ (255) | $ 479 |
Net operating losses | 2,839 | 5,507 |
Impairment - oil and natural gas properties | 0 | 0 |
Other | 27 | 438 |
Total deferred tax asset | 2,611 | 6,424 |
Less: valuation allowance | (2,611) | (6,424) |
Total deferred tax assets | $ 0 | $ 0 |
14. INCOME TAXES (Details Narrative) $ in Thousands |
6 Months Ended |
---|---|
Jun. 30, 2017
USD ($)
| |
Income Tax Disclosure [Abstract] | |
Net change in valuation allowance | $ 3,813 |
Federal net operating loss carryforwards | 82,290 |
State net operating loss carryforwards | $ 49,922 |
Federal net operating loss carryforwards, expiration date | 2033 |
State net operating loss carryforwards, expiration date | 2023 |
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