Notes to Unaudited Condensed Consolidated Financial Statements
Electricity from the Company’s methane facility was sold on a long term contract. There were no specific volumes of electricity that were required to be delivered under this contract. Electricity passed through sales meters located at the Carter Valley landfill site, at which time control of the electricity transferred to the purchaser, the Company’s contractual obligation was satisfied, and revenues were recognized
.
The Company sold its methane facility assets on January 26, 2018 and therefore will not recognize revenues associated with any sales volumes after this date. Revenues associated with the methane facility are included in Discontinued Operations. (See Note 11. Discontinued Operations)
The Company operates certain salt water disposal wells, some of which accept water from third parties. The contracts with the third parties primarily require a flat monthly fee for the third parties to dispose water into the wells. In some cases, the contract is based on a per barrel charge to dispose water into the wells. There is no requirement under the contracts for these third parties to use these wells for their water disposal. If the third parties do dispose water into the Company operated wells in a given month, the Company has met its contractual obligations and revenues are recognized for that month.
The following table presents the disaggregated revenue by commodity for the three months ended March 31, 2018 and 2017 (in thousands):
|
|
Three Months Ended
|
|
|
|
March 31, 2018
|
|
|
March 31, 2017
|
|
Revenues (in thousands):
|
|
|
|
|
|
|
Crude oil
|
|
$
|
1,357
|
|
|
$
|
1,203
|
|
Salt water disposal fees
|
|
|
10
|
|
|
|
6
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$
|
1,367
|
|
|
$
|
1,209
|
|
There were no natural gas imbalances at March 31, 2018 or December 31, 2017.
Cash and Cash Equivalents
Cash and cash equivalents include temporary cash investments with a maturity of ninety days or less at date of purchase.
Inventory
Inventory consists of crude oil in tanks and is carried at lower of cost or market value. The cost component of the oil inventory is calculated using the average cost per barrel for the three months ended March 31, 2018 and December 31, 2017. These costs includes production costs and taxes, allocated general and administrative costs, depletion, and allocated interest cost. The market value component is calculated using the average March 2018 and December 2017 oil sales prices received from the Company’s Kansas properties. In addition, the Company also carried equipment and materials to be used in its Kansas operation and is carried at the lower of cost or market value. The cost component of the equipment and materials inventory represents the original cost paid for the equipment and materials. The market component is based on estimated sales value for similar equipment and materials at the end of each period. At March 31, 2018 and December 31, 2017, inventory consisted of the following
(in thousands)
:
|
|
March 31,
2018
|
|
|
December 31,
2017
|
|
Oil – carried at cost
|
|
$
|
551
|
|
|
$
|
436
|
|
Equipment and materials – carried at market
|
|
|
105
|
|
|
|
105
|
|
Total inventory
|
|
$
|
656
|
|
|
$
|
541
|
|
Full Cost Method of Accounting
The Company follows the full cost method of accounting for oil and gas property acquisition, exploration, and development activities. Under this method, all costs incurred in connection with acquisition, exploration, and development of oil and gas reserves are capitalized. Capitalized costs include lease acquisitions, seismic related costs, certain internal exploration costs, drilling, completion, and estimated asset retirement costs. The capitalized costs of oil and gas properties, plus estimated future development costs relating to proved reserves and estimated asset retirement costs which are not already included net of estimated salvage value, are amortized on the unit-of-production method based on total proved reserves. The Company has determined its reserves based upon reserve reports provided by LaRoche Petroleum Consultants Ltd. since 2009. The costs of unproved properties are excluded from amortization until the properties are evaluated, subject to an annual assessment of whether impairment has occurred. The Company had $0 in unevaluated properties as of March 31, 2018 and December 31, 2017. Proceeds from the sale of oil and gas properties are accounted for as reductions to capitalized costs unless such sales cause a significant change in the relationship between costs and the estimated value of proved reserves, in which case a gain or loss is recognized.
Tengasco, Inc. and Subsidiaries
Notes to Unaudited Condensed Consolidated Financial Statements
At the end of each reporting period, the Company performs a “ceiling test” on the value of the net capitalized cost of oil and gas properties. This test compares the net capitalized cost (capitalized cost of oil and gas properties, net of accumulated depreciation, depletion and amortization and related deferred income taxes) to the present value of estimated future net revenues from oil and gas properties using an average price (arithmetic average of the beginning of month prices for the prior 12 months) and current cost discounted at 10% plus cost of properties not being amortized and the lower of cost or estimated fair value of unproven properties included in the cost being amortized (ceiling). If the net capitalized cost is greater than the ceiling, a write-down or impairment is required. A write-down of the carrying value of the asset is a non-cash charge that reduces earnings in the current period. Once incurred, a write-down may not be reversed in a later period.
Accounts Receivable
Accounts receivable consist of uncollateralized joint interest owner obligations due within 30 days of the invoice date, uncollateralized accrued revenues due under normal trade terms, generally requiring payment within 30 days of sales of oil and gas production and within 60 days of sales of produced electricity, and other miscellaneous receivables. No interest is charged on past-due balances. Payments made on accounts receivable are applied first to the earliest unpaid items. We review accounts receivable periodically and reduce the carrying amount by a valuation allowance that reflects our best estimate of the amount that may not be collectible. An allowance was recorded at March 31, 2018 and December 31, 2017.
The following table sets forth information concerning the Company’s accounts receivable
(in thousands)
:
|
|
March 31,
2018
|
|
|
December 31,
2017
|
|
Revenue
|
|
$
|
519
|
|
|
$
|
479
|
|
Joint interest
|
|
|
23
|
|
|
|
23
|
|
Other
|
|
|
22
|
|
|
|
29
|
|
Allowance for doubtful accounts
|
|
|
(14
|
)
|
|
|
(14
|
)
|
Total accounts receivable
|
|
$
|
550
|
|
|
$
|
517
|
|
Reclassifications
Certain prior year amounts have been reclassified to conform to current year presentation with no effect on net income.
The Company incurred a net loss of approximately $574,000 in 2017. In January 2018, the Company sold its methane facility for $2.65 million. During 2018, the Company believes its revenues as well as the proceeds received from the sale of the methane facility will be sufficient to fund operating and general and administrative expenses and to remain in compliance with its bank covenants. If revenues and the proceeds from the sale of the methane facility are not sufficient to fund these expenses or if the Company needs additional funds for capital spending, the Company could borrow funds against the credit facility as this facility currently has a $2.0 million borrowing base with no funds currently drawn. In addition, if required, the Company could also issue additional shares of stock and/or sell assets as needed to further fund operations.
Income taxes are reported in accordance with U.S. GAAP, which requires the establishment of deferred tax accounts for all temporary differences between the financial reporting and tax bases of assets and liabilities, using currently enacted federal and state income tax rates. In addition, deferred tax accounts must be adjusted to reflect new rates if enacted into law.
The deferred income tax assets or liabilities for an oil and gas exploration and development company are dependent on many variables such as estimates of the economic lives of depleting oil and gas reserves and commodity prices. Accordingly, the asset or liability is subject to continuous recalculation, and revision of the numerous estimates required, and may change significantly in the event of occurrences such as major acquisitions, divestitures, commodity price changes, changes in reserve estimates, changes in reserve lives, and changes in tax rates or tax laws.
Tengasco, Inc. and Subsidiaries
Notes to Unaudited Condensed Consolidated Financial Statements
At December 31, 2017, federal net operating loss carryforwards amounted to approximately $30.2 million which expire between 2019 and 2036. The net total deferred tax asset was $242,000 at March 31, 2018 and December 31, 2017. In 2017, The Company released a portion of the allowance related to the Company’s Minimum Tax Credit (“MTC”) as a result of the 2017 Tax Act. The Company recorded an allowance on the remaining deferred tax asset at March 31, 2018 and December 31, 2017 primarily due to cumulative losses incurred during the 3 years ended December 31, 2017. The Company expects to utilize its net operating losses and reduce its valuation allowance to offset taxable income resulting from the sale of the methane facility assets. There were no recorded unrecognized tax benefits at March 31, 2018.
Common Stock
On January 2, 2018, 4,569 common shares were issued in the aggregate to the Company’s four directors and CFO and interim CEO.
Rights Agreement
Effective March 17, 2017 the Board of Directors declared a dividend of one right (a “Right”) for each of the Company’s issued and outstanding shares of common stock, $0.001 par value per share (“Common Stock”). The dividend was paid to the stockholders of record at the close of business on March 27, 2017 (the “Record Date”). Each Right entitles the registered holder, subject to the terms of the Rights Agreement dated as of March 16, 2017 (the “Rights Agreement”) between the Company and the Rights Agent, Continental Stock Transfer & Trust Company, to purchase from the Company one one-thousandth of a share of the Company’s Series A Preferred Stock at a price of $1.10 (the “Exercise Price”), subject to certain adjustments.
The purpose of the Rights Agreement is to reduce the risk that the Company’s ability to use its net operating losses to reduce potential future federal income tax obligations would be limited by reason of the Company’s experiencing an “ownership change,” as defined in Section 382 of the Internal Revenue Code. A company generally experiences an ownership change if the percentage of its stock owned by its “5-percent shareholders,” as defined in Section 382 of the Tax Code, increases by more than 50 percentage points over a rolling three-year period. The Rights Agreement is designed to reduce the likelihood that the Company will experience an ownership change under Section 382 of the Tax Code by discouraging any person or group from becoming a 4.95% shareholder and also discouraging any existing 4.95% (or more) shareholder from acquiring additional shares of the Company’s stock.
The Rights will not be exercisable until the “Distribution Date”, which is generally defined as the earlier to occur of:(i) a public announcement or filing that a person or group has, become an “Acquiring Person” which is defined as a person or group of affiliated or associated persons or persons acting in concert who, at any time after the date of the Rights Agreement, have acquired, or obtained the right to acquire, beneficial ownership of 4.95% or more of the Company’s outstanding shares of Common Stock; or a person or group currently owning 4.95% (or more) of the Company’s outstanding shares acquires additional shares of the Company’s stock; subject to certain exceptions; or (ii) the commencement of, or announcement of an intention to commence, a tender offer or exchange offer the consummation of which would result in any person becoming an Acquiring Person.
The Rights will expire prior to the earlier of March 16, 2020; or a date the Board of Directors determines by resolution in its business judgment that the Agreement is no longer necessary or appropriate; or in certain other specified circumstances.
At any time after any person or group of affiliated or associated persons becomes an Acquiring Person, the Board, at its option, may exchange each Right (other than Rights owned by such person or group of affiliated or associated persons which will have become void), in whole or in part, at an exchange ratio of two shares of Common Stock per outstanding Right (subject to adjustment).
For further information on the Rights Agreement, please refer to the Rights Agreement that was attached in full as an exhibit to the Company’s Form 8-K filed with SEC on March 17, 2017.
Preferred Stock
Series A Preferred Stock has a par value of $0.0001 and 10,000 shares have been designated. No shares of Series A Preferred Stock have been issued by the Company pursuant to the Rights Agreement described above or otherwise.
Tengasco, Inc. and Subsidiaries
Notes to Unaudited Condensed Consolidated Financial Statements
(5)
|
Earnings per Common Share
|
We report basic earnings per common share, which excludes the effect of potentially dilutive securities, and diluted earnings per common share which include the effect of all potentially dilutive securities unless their impact is anti-dilutive. The following are reconciliations of the numerators and denominators of our basic and diluted earnings per share, (in thousands except for share and per share amounts):
|
|
For the Three Months Ended
March 31,
|
|
|
|
2018
|
|
|
2017
|
|
Income (numerator):
|
|
|
|
|
|
|
Net income (loss) from continuing operations
|
|
$
|
133
|
|
|
$
|
(170
|
)
|
Net income (loss) from discontinued operations
|
|
$
|
1,110
|
|
|
$
|
(43
|
)
|
Weighted average shares (denominator):
|
|
|
|
|
|
|
|
|
Weighted average shares – basic
|
|
|
10,624,442
|
|
|
|
8,452,132
|
|
Dilution effect of share-based compensation, treasury method
|
|
|
—
|
|
|
|
—
|
|
Weighted average shares – dilutive
|
|
|
10,624,442
|
|
|
|
8,452,132
|
|
Income (loss) per share – Basic and Dilutive:
|
|
|
|
|
|
|
|
|
Continuing operations
|
|
$
|
0.01
|
|
|
$
|
(0.02
|
)
|
Discontinued operations
|
|
$
|
0.10
|
|
|
$
|
(0.01
|
)
|
Options issued to the Company’s directors in which the exercise price was higher than the average market price each quarter were excluded from diluted shares.
(6)
|
Recent Accounting Pronouncements
|
In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2014–09
Revenue from Contracts with Customers (“ASU 2014-09”).
This ASU, as amended, superseded virtually all of the revenue recognition guidance in generally accepted accounting principles in the United States. The core principle of the five–step model is that an entity will recognize revenue when it transfers control of goods or services to customers at an amount that reflects the consideration to which it expects to be entitled in exchange for those goods or services. Entities can choose to apply the standard using either the full retrospective approach or a modified retrospective approach. The provisions of ASU 2014–09 are applicable to annual reporting periods beginning after December 15, 2017 and interim periods within those annual periods. To date, the Company has identified the contracts with each of its customers and the separate performance obligations associated with each of these contracts. Based on the evaluation performed to date, we have identified similar performance obligations as compared with deliverables and separate units of account previously identified, and we do not expect any change related to the allocation of the transaction price and the timing of our revenue to have a material impact on our consolidated financial statements or results of operations.
T
he Company implemented ASU 2014-09 as of January 1, 2018 using the modified retrospective approach with no impact on the Company’s operating results or cash flows.
In February 2016, the FASB issued
Update 2016-02
Leases (Topic 842).
This guidance was issued to
increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements
.
This guidance
is e
ffective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. Early application of the amendments in this Update is permitted for all entities. To date, the Company has identified each of its leases and is in the process of determining the impact of this new guidance on each of the identified leases. The Company does not expect this to impact its operating results or cash flows, however, the Company does expect to carry a portion of future lease costs as an asset and a liability on its balance sheet.
Tengasco, Inc. and Subsidiaries
Notes to Unaudited Condensed Consolidated Financial Statements
In August 2016, the FASB issued
Update 2016-15
Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments.
This amendment provides guidance on certain cash flow classification issues, thereby reducing the current and potential future diversity in practice
.
This guidance is
effective for annual periods beginning after December 15, 2017, and interim periods within those annual periods. Early adoption is permitted for any entity in any interim or annual period. If an entity early adopts the amendments in an interim period, any adjustments should be reflected as of the beginning of the fiscal year that includes that interim period. An entity that elects early adoption must adopt all of the amendments in the same period. T
he Company implemented this in 2018 with no impact on the Company’s operating results or cash flows
.
(7)
|
Related Party Transactions
|
On September 17, 2007, Hoactzin Partners, L.P. (“Hoactzin”) subscribed to a drilling program offered by the Company consisting of wells to be drilled on the Company’s Kansas Properties (the “Program”). Peter E. Salas, the Chairman of the Board of Directors of the Company, is the controlling person of Hoactzin and of Dolphin Offshore Partners, L.P., the Company’s largest shareholder. Hoactzin was also conveyed a net profits interest in the MMC facility at the Carter Valley municipal solid waste landfill owned and operated by Republic Services, Inc. in Church Hill, Tennessee where the Company installed a propriety combination of advanced gas treatment technology to extract the methane component of the purchased gas stream (the “Methane Project”). The net profits interest owned by Hoactzin during 2018 was 7.5% of the net profits as defined by agreement and takes into account specific costs and expenses as well as gross gas revenues for the project. As a result of the startup costs, monthly operating expenses, and gas production levels experienced, no net profits as defined were realized during the period from the project startup in April, 2009 through the sale of the Methane Project and other related assets in 2018. The Company sold all of the Methane Project and all its other methane facility assets, except the applicable U.S. patent, on January 26, 2018.
On December 18, 2007, the Company entered into a Management Agreement with Hoactzin to manage on behalf of Hoactzin all of its working interest in certain oil and gas properties owned by Hoactzin and located in the onshore Texas Gulf Coast, and offshore Texas and offshore Louisiana. As part of the consideration for the Company’s agreement to enter into the Management Agreement, Hoactzin granted to the Company an option to participate in up to a 15% working interest on a dollar for dollar cost basis in any new drilling or workover activities undertaken on Hoactzin’s managed properties during the term of the Management Agreement. The Management Agreement expired on December 18, 2012.
The Company entered into a transition agreement with Hoactzin whereby the Company no longer performs operations, but administratively assists Hoactzin in becoming operator of record of these wells and transferring all bonds from the Company to Hoactzin. This assistance is primarily related to signing the necessary documents to effectuate this transition. Hoactzin and its controlling member are indemnifying the Company for any costs or liabilities incurred by the Company resulting from such assistance, or the fact that the Company is the operator of record on certain of these wells. As of the date of this Report, the Company continues to administratively assist Hoactzin with this transition process.
As operator during the term of the Management Agreement that expired in 2012, the Company routinely contracted in its name for goods and services with vendors in connection with its operation of the Hoactzin properties. In practice, Hoactzin directly paid these invoices for goods and services that were contracted in the Company’s name. As a result of the operations performed in late 2009 and early 2010, Hoactzin had significant past due balances to several vendors, a portion of which were included on the Company’s balance sheet. Payables related to these past due and ongoing operations remained outstanding at March 31, 2018 and December 31, 2017 in the amount of $159,000. The Company has recorded the Hoactzin-related payables and the corresponding receivable from Hoactzin as of March 31, 2018 and December 31, 2017 in its Consolidated Balance Sheets under “Accounts payable – other” and “Accounts receivable – related party”. The outstanding balance of $159,000 should not increase in the future. However, Hoactzin has not made payments to reduce the $159,000 of past due balances from 2009 and 2010 since the second quarter of 2012. Based on these circumstances, the Company has elected to record an allowance in the amount of $159,000 for the balances outstanding at March 31, 2018 and December 31, 2017. This allowance was recorded in the Company’s Consolidated Balance Sheets under “Accounts receivable – related party”. The resulting balances recorded in the Company’s Consolidated Balance Sheets under “Accounts receivable – related party, less allowance for doubtful accounts of $159” are $0 at March 31, 2018 and December 31, 2017.
Tengasco, Inc. and Subsidiaries
Notes to Unaudited Condensed Consolidated Financial Statements
(8)
|
Oil and Gas Properties
|
The following table sets forth information concerning the Company’s oil and gas properties
(in thousands)
:
|
|
March 31,
2018
|
|
|
December 31,
2017
|
|
Oil and gas properties
|
|
$
|
5,733
|
|
|
$
|
5,704
|
|
Unevaluated properties
|
|
|
—
|
|
|
|
—
|
|
Accumulated depreciation, depletion, and amortization
|
|
|
(1,163
|
)
|
|
|
(984
|
)
|
Oil and gas properties
|
|
$
|
4,570
|
|
|
$
|
4,720
|
|
The Company recorded depletion expense of $172,000 and $204,000 for the three months ended March 31, 2018 and 2017, respectively. During the three months ended March 31, 2018 and 2017, the Company also recorded in “Accumulated depreciation, depletion, and amortization” a $7,000 gain on asset retirement obligations and a $1,000 gain on asset retirement obligations, respectively.
(9)
|
Asset Retirement Obligation
|
Our asset retirement obligations represent the estimated present value of the amount we will incur to plug, abandon, and remediate our producing properties at the end of their productive lives in accordance with applicable laws. The following table summarizes the Company’s Asset Retirement Obligation transactions for the three months ended March 31, 2018
(in thousands)
:
Balance December 31, 2017
|
|
$
|
2,270
|
|
Accretion expense
|
|
|
36
|
|
Liabilities incurred
|
|
|
—
|
|
Liabilities settled
|
|
|
(14
|
)
|
Balance March 31, 2018
|
|
$
|
2,292
|
|
Long-term debt to unrelated entities consisted of the following
(in thousands)
:
|
|
March 31,
2018
|
|
|
December 31,
2017
|
|
Note payable to a financial institution, with interest only payment until maturity
|
|
$
|
—
|
|
|
$
|
—
|
|
Installment notes bearing interest at the rate of 4.16% to 4.60% per annum collateralized by vehicles with monthly payments including interest, insurance and maintenance of approximately $10
|
|
|
159
|
|
|
|
90
|
|
Total debt
|
|
|
159
|
|
|
|
90
|
|
Less current maturities
|
|
|
(56
|
)
|
|
|
(41
|
)
|
Long-term debt, less current maturities
|
|
$
|
103
|
|
|
$
|
49
|
|
At March 31, 2018, the Company had a revolving credit facility with Prosperity Bank. This has historically been the Company’s primary source to fund working capital and future capital spending. Under the credit facility, loans and letters of credit are available to the Company on a revolving basis in an amount outstanding not to exceed the lesser of $50 million or the Company’s borrowing base in effect from time to time. As of March 31, 2018, the Company’s borrowing base was $2 million. The credit facility is secured by substantially all of the Company’s producing and non-producing oil and gas properties. The credit facility includes certain covenants with which the Company is required to comply. At March 31, 2018, these covenants include the following: (a) Current Ratio > 1:1; (b) Funded Debt to EBITDA < 3.5x; and (c) Interest Coverage > 3.0x. At March 31, 2018, the interest rate on this credit facility was 5.25%. The Company was in compliance with all covenants during the quarter ended March 31, 2018.
Tengasco, Inc. and Subsidiaries
Notes to Unaudited Condensed Consolidated Financial Statements
On March 21, 2018, the Company’s senior credit facility with Prosperity Bank after Prosperity Bank’s most recent review of the Company’s currently owned producing properties was amended to increase the borrowing base to $2 million and the maturity date was extended to July 31, 2020. The borrowing base remains subject to the existing periodic redetermination provisions in the credit facility. The interest rate remained prime plus 0.50% per annum. This rate was 5.00% at the date of the amendment. The maximum line of credit of the Company under the Prosperity Bank credit facility remained $50 million and the Company had no outstanding borrowing under the facility as of March 31, 2018. The next borrowing base review will take place in July 2018.
(11)
|
Discontinued Operations
|
The following table sets forth information concerning the Discontinued Operations
(in thousands):
|
|
March 31,
2018
|
|
|
December 31,
2017
|
|
Accounts receivable
|
|
$
|
—
|
|
|
$
|
91
|
|
Other current assets
|
|
|
—
|
|
|
|
30
|
|
Discontinued operations included in current assets
|
|
$
|
—
|
|
|
$
|
121
|
|
|
|
|
|
|
|
|
|
|
Property, plant, and equipment
|
|
$
|
—
|
|
|
$
|
1,681
|
|
Accumulated depreciation, depletion, and amortization
|
|
|
—
|
|
|
|
(184
|
)
|
Discontinued operations included in non-current assets
|
|
$
|
—
|
|
|
$
|
1,497
|
|
|
|
|
|
|
|
|
|
|
Accounts payable - trade
|
|
$
|
32
|
|
|
$
|
27
|
|
Accrued and other current liabilities
|
|
|
—
|
|
|
|
16
|
|
Discontinued operations included in current liabilities
|
|
$
|
32
|
|
|
$
|
43
|
|
|
|
For the Three Months Ended
March 31,
|
|
|
|
2018
|
|
|
2017
|
|
|
|
|
|
|
|
|
Revenues
|
|
$
|
6
|
|
|
$
|
135
|
|
Production costs and taxes
|
|
|
(50
|
)
|
|
|
(163
|
)
|
Depreciation, depletion, and amortization
|
|
|
(4
|
)
|
|
|
(15
|
)
|
Interest income
|
|
|
1
|
|
|
|
—
|
|
Gain on sale of assets
|
|
|
1,157
|
|
|
|
—
|
|
Deferred income tax benefit
|
|
|
—
|
|
|
|
—
|
|
Net income (loss) from discontinued operations
|
|
$
|
1,110
|
|
|
$
|
(43
|
)
|
The Discontinued Operations are related to the Manufactured Methane facilities. The Company sold all its methane facility assets, except the applicable U.S. patent, on January 26, 2018 for $2.65 million.
(12)
|
Fair Value Measurements
|
FASB ASC 820, “Fair Value Measurements and Disclosures”, establishes a framework for measuring fair value. That framework provides a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets and liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements). The three levels of the fair value hierarchy under FASB ASC 820 are described as follows:
Tengasco, Inc. and Subsidiaries
Notes to Unaudited Condensed Consolidated Financial Statements
Level 1 – Observable inputs, such as unadjusted quoted prices in active markets, for substantially identical assets and liabilities.
Level 2 – Observable inputs other than quoted prices within Level 1 for similar assets and liabilities. These include quoted prices for similar assets and liabilities in active markets, quoted prices for identical assets and liabilities in markets that are not active, or other inputs that are observable or can be corroborated by observable market data. If the asset or liability has a specified or contractual term, the input must be observable for substantially the full term of the asset or liability.
Level 3 – Unobservable inputs that are supported by little or no market activity, generally requiring a significant amount of judgment by management. The assets or liabilities fair value measurement level within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement. Valuation techniques used need to maximize the use of observable inputs and minimize the use of unobservable inputs.
The methods described above may produce a fair value calculation that may not be indicative of net realizable value or reflective of future fair values. Further, although the Company believes its valuation methods are appropriate and consistent with other market participants, the use of different methodologies or assumptions to determine the fair value of certain financial instruments could result in a different fair value measurement at the reporting date.
Upon completion of wells, the Company records an asset retirement obligation at fair value using Level 3 assumptions.
Nonfinancial assets and liabilities are measured at fair value on a nonrecurring basis upon impairment. The carrying amounts of other financial instruments including cash and cash equivalents, accounts receivable, account payables, accrued liabilities and long term debt in our balance sheet approximates fair value as of March 31, 2018 and December 31, 2017.
(13)
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Commitments and Contingencies
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The Company as designated operator of the Hoactzin properties was administratively issued an “Incident of Non-Compliance” by BSEE during the quarter ended September 30, 2012 concerning one of Hoactzin’s operated properties. This action called for payment of a civil penalty of $386,000 for failure to provide, upon request, documentation to the BSEE evidencing that certain safety inspections and tests had been conducted in 2011. On July 14, 2015, the federal district court in the Eastern District of Louisiana affirmed the civil penalty without reduction. The Company did not further appeal. In the third quarter of 2015, the Company paid the civil penalty and statutory interest thereon from funds borrowed under its credit facility. In the fourth quarter of 2015, the Company received a return of the cash collateral previously provided to RLI Insurance Company. The Company has not advanced any funds to pay any obligations of Hoactzin and no borrowing capability of the Company has been used in connection with its obligations under the Management Agreement, except for those funds used to pay the civil penalty and interest thereon.
During the second quarter of 2015, the Company received from Hoactzin a copy of an internal analysis prepared by Hoactzin setting out certain issues that Hoactzin may consider to form the basis of operational and other claims against the Company primarily under the Management Agreement. This analysis raised issues other than the “Incident of Non-Compliance” discussed above. The Company is discussing this analysis, as well as the civil penalty discussed above, with Hoactzin in an effort to determine whether there is possibility of a reasonable resolution of some or all of these matters on a negotiated basis.
In the normal course of business, the Company enters into commitments to spend capital on oil and gas properties. Since March 31, 2018, the Company has entered into a drilling commitment in the amount of approximately $45,000. The work associated with this commitment was completed in April 2018.
Cost Reduction Measures
Commencing in the quarter ended March 31, 2015 and continuing through the quarter ended March 31, 2018, the Company implemented cost reduction measures including compensation reductions for each employee as well as members of the Board of Directors. These compensation reductions will remain in place until such time, if any, that the market price of crude oil, calculated as a thirty day trailing average of WTI postings as published by the U.S. Energy Information Administration meets or exceeds $70 per barrel when compensation shall revert to the levels in place before the reductions became effective. At such time, if any, that the market price of crude oil, calculated as a thirty day trailing average of WTI postings as published by the U.S. Energy Information Administration meets or exceeds $85 per barrel, all previous reductions made will be reimbursed, a portion which may be paid in stock, to each employee and members of the Board of Directors if is still employed by the Company or still a member of the Board of Directors. For the period January 1, 2015 through March 31, 2018, the reductions were approximately $421,000. The Company has not accrued any liabilities associated with these compensation reductions.
Tengasco, Inc. and Subsidiaries
Notes to Unaudited Condensed Consolidated Financial Statements
Legal Proceedings
The Company is not a party to any pending material legal proceeding. To the knowledge of management, no federal, state, or local governmental agency is presently contemplating any proceeding against the Company which would have a result materially adverse to the Company. To the knowledge of management, no director, executive officer or affiliate of the Company or owner of record or beneficially of more than 5% of the Company’s common stock is a party adverse to the Company or has a material interest adverse to the Company in any proceeding.