UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

 

FORM 10-Q

 

(Mark One)

For the quarterly period ended: March 31, 2020

OR

For the transition period from                      to                     

Commission file number: 001-34574

 

TRANSATLANTIC PETROLEUM LTD.

(Exact name of registrant as specified in its charter)

 

 

Registrant’s Telephone Number, Including Area Code: (214) 220-4323

 

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

 

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

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant is required to submit such files).    Yes  ☒    No  ☐

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

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

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

As of June 12, 2020, the registrant had 62,719,448‬ common shares outstanding.

 

 

 

TABLE OF CONTENTS

 

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As previously disclosed in the Current Report on Form 8-K filed by TransAtlantic Petroleum Ltd. (together with its subsidiaries, “we,” “us,” “our,” the “Company,” or “TransAtlantic”) on May 14, 2020, we delayed the filing of this Quarterly Report on Form 10-Q due to circumstances related to the COVID-19 pandemic and in reliance on the order of the U.S. Securities and Exchange Commission (the “SEC”) under Section 36 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), and certain rules thereunder (Release No. 34-88465) (the “Order”). The Order allows a registrant up to an additional 45 days after the original due date of certain reports required to be filed with the SEC if a registrant’s ability to file such report timely is affected due to COVID-19.

Our business has experienced disruptions due to the unprecedented conditions surrounding the COVID-19 pandemic, including, but not limited to, the limited availability of key personnel and professional advisors who are needed to prepare this Quarterly Report on Form 10-Q due in part to suggested and mandated social quarantining and work from home orders. This has, in turn, delayed our ability to prepare this Quarterly Report on Form 10-Q in a timely manner.

Forward-Looking Statements

Certain statements in this Quarterly Report on Form 10-Q constitute “forward-looking statements” within the meaning of applicable U.S. and Canadian securities legislation. Additionally, forward-looking statements may be made orally or in press releases, conferences, reports, on our website or otherwise, in the future, by us or on our behalf. Such statements are generally identifiable by the terminology used such as “plans,” “expects,” “estimates,” “budgets,” “intends,” “anticipates,” “believes,” “projects,” “indicates,” “targets,” “objective,” “could,” “should,” “may,” or other similar words.

By their very nature, forward-looking statements require us to make assumptions that may not materialize or that may not be accurate. Forward-looking statements are subject to known and unknown risks and uncertainties and other factors that may cause actual results, levels of activity, and achievements to differ materially from those expressed or implied by such statements, including the factors discussed under Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2019. Such factors include, but are not limited to, the following: our ability to continue as a going concern; well development results; access to sufficient capital; market prices for natural gas, natural gas liquids, and oil products, including price changes resulting from COVID-19 fears as well as oil oversupply concerns; estimates of reserves and economic assumptions; the ability to produce and transport natural gas, natural gas liquids, and oil products, including price changes resulting from coronavirus fears as well as oil oversupply concerns; the results of exploration and development drilling and related activities; the effects of the coronavirus on our operations, demand for oil and natural gas as well as governmental actions in response to the coronavirus; economic conditions in the countries and provinces in which we carry on business, especially economic slowdowns; actions by governmental authorities; the unwinding of our hedges against a decline in the price of oil; receipt of required approvals; increases in taxes; legislative and regulatory initiatives relating to fracture stimulation activities; changes in environmental and other regulations; renegotiations of contracts; political uncertainty, including sanctions, armed conflicts, and actions by insurgent groups; outcomes of litigation; the negotiation and closing of material contracts; and the other factors discussed in other documents that we file with or furnish to the SEC and Canadian securities regulatory authorities. The impact of any one factor on a particular forward-looking statement is not determinable with certainty as such factors are interdependent upon other factors and our course of action would depend upon our assessment of the future, considering all information then available. In that regard, any statements as to: liquidity; ability to continue as a going concern; COVID-19; access to sufficient capital; future oil or natural gas production levels; capital expenditures; asset sales; the allocation of capital expenditures to exploration and development activities; sources of funding for our capital expenditure programs or operations; drilling of new wells; demand for oil and natural gas products; expenditures and allowances relating to environmental matters; dates by which certain areas will be developed or will come on-stream; expected finding and development costs; future production rates; ultimate recoverability of reserves, including the ability to convert probable and possible reserves to proved reserves; dates by which transactions are expected to close; future cash flows, uses of cash flows, collectability of receivables and availability of trade credit; expected operating costs; changes in any of the foregoing; and other statements using forward-looking terminology are forward-looking statements, and there can be no assurance that the expectations conveyed by such forward-looking statements will, in fact, be realized.

Although we believe that the expectations conveyed by the forward-looking statements are reasonable based on information available to us on the date such forward-looking statements were made, no assurances can be given as to future results, levels of activity, achievements or financial condition.

Readers should not place undue reliance on any forward-looking statement and should recognize that the statements are predictions of future results, which may not occur as anticipated. Actual results could differ materially from those anticipated in the forward-looking statements and from historical results, due to the risks and uncertainties described above, as well as others not now anticipated. The foregoing statements are not exclusive and further information concerning us, including factors that potentially could materially affect our financial results, may emerge from time to time. We do not intend to update forward-looking statements to reflect actual results or changes in factors or assumptions affecting such forward-looking statements, except as required by law.

 

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PART I. FINANCIAL INFORMATION

TRANSATLANTIC PETROLEUM LTD.

Consolidated Balance Sheets

(in thousands of U.S. Dollars, except share data)

 

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

 

 

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TRANSATLANTIC PETROLEUM LTD.

Consolidated Statements of Operations and Comprehensive (Loss) Income

(Unaudited)

(U.S. Dollars and shares in thousands, except per share amounts)

 

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

 

 

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TRANSATLANTIC PETROLEUM LTD.

Consolidated Statement of Equity for the Three Months Ended March 31, 2020 and 2019

(Unaudited)

(U.S. Dollars and shares in thousands)

 

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

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

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TRANSATLANTIC PETROLEUM LTD.

Consolidated Statements of Cash Flows

(Unaudited)

(in thousands of U.S. Dollars)

 

 

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

 

 

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Transatlantic Petroleum Ltd.

Notes to Consolidated Financial Statements

(Unaudited)

1. General

Nature of operations

TransAtlantic Petroleum Ltd. (together with its subsidiaries, “we,” “us,” “our,” the “Company,” or “TransAtlantic”) is an international oil and natural gas company engaged in acquisition, exploration, development, and production. We have focused our operations in countries that have established, yet underexplored petroleum systems, are net importers of petroleum, have an existing petroleum transportation infrastructure, and provide favorable commodity pricing, royalty rates, and tax rates to exploration and production companies. We hold interests in developed and undeveloped oil and natural gas properties in Turkey and Bulgaria. As of June 22, 2020, approximately 49.9% of our outstanding common shares were beneficially owned by N. Malone Mitchell 3rd, our chief executive officer and chairman of our board of directors. Persons and entities associated with Mr. Mitchell also owned 739,000 of our 12.0% Series A Convertible Redeemable Preferred Shares (“Series A Preferred Shares”). Mr. Mitchell’s affiliates are currently prohibited from converting any of their Series A Preferred Shares to common shares if such conversion would cause Mr. Mitchell or his affiliates to obtain beneficial ownership in excess of 49.9% of the outstanding common shares; however, Mr. Mitchell, upon 61 days’ prior notice, may increase or decrease such percentage cap.

We are a holding company with two operating segments – Turkey and Bulgaria. Our assets consist of our ownership interests in subsidiaries that primarily own assets in Turkey and Bulgaria.

Basis of presentation

Our consolidated financial statements are expressed in U.S. Dollars (“USD”) and have been prepared by management in accordance with accounting principles generally accepted in the United States (“U.S. GAAP”). All amounts in the notes to the consolidated financial statements are in USD unless otherwise indicated. The unaudited consolidated financial statements include accounts of the Company and its wholly-owned subsidiaries. All significant intercompany balances and transactions have been eliminated in consolidation. In preparing financial statements, management makes informed judgments and estimates that affect the reported amounts of assets and liabilities as of the date of the financial statements and affect the reported amounts of revenues and expenses during the reporting period. On an ongoing basis, management reviews estimates, including those related to fair value measurements associated with financial derivatives, the recoverability and impairment of long-lived assets, contingencies and income taxes. Changes in facts and circumstances may result in revised estimates and actual results may differ from these estimates.

Certain information and footnote disclosures normally included in the consolidated financial statements prepared in accordance with U.S. GAAP have been condensed or omitted in this Form 10-Q pursuant to the rules and regulations of the SEC. These consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2019.

2. Going Concern

These consolidated financial statements have been prepared on the basis of accounting principles applicable to a going concern.  These principles assume that we will be able to realize our assets and discharge our obligations in the normal course of operations for the foreseeable future.  

We incurred a net loss of $24.0 million for the three months ended March 31, 2020.  At March 31, 2020, we had cash and cash equivalents of $12.8 million, $ 10.6 million in short-term debt, and a working capital surplus of $5.9 million, compared to cash and cash equivalents of $9.7 million, $2.9 million in long-term debt, $17.1 million in short-term debt and a working capital surplus of $2.0 million at December 31, 2019.

In March 2020, crude oil prices declined to approximately $25 per barrel for Brent crude as a result of market concerns about the economic impact from the COVID-19 as well as the ability of OPEC and Russia to agree on a perceived need to implement further production cuts in response to weaker worldwide demand.  Since then, Brent crude prices have rebounded to approximately $39.00 per barrel as of June 12, 2020 and remain volatile and unpredictable. The current futures forward curve for Brent crude indicates that prices may continue at or near current prices for an extended time.

As a result of the decline in Brent crude prices, the current near term price outlook and resulting lower current and projected cash flows from operations, we have reduced our planned capital expenditures to those necessary for production lease maintenance and those projecting a return on invested capital at current prices. In order to mitigate the impact of reduced prices on our 2020 cash flows and liquidity, we implemented cost reduction measures to reduce our operating costs and general and administrative expenses. In

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connection therewith, we intend to prioritize funding operating expenditures over general and administrative expenditures, whenever possible.

On March 9, 2020, we unwound our commodity derivative contracts with respect to our future crude oil production. In connection with these transactions, we received $6.5 million. In order to reduce future interest expense, we used these proceeds to pay down the 2019 Term Loan (as defined in Note 8. “Loans Payable”). On April 3, 2020, we entered into a new swap contract with DenizBank, A.S. (“DenizBank”), which hedged approximately 2,000 barrels of oil per day. The swap contract is in place from May 2020 through February 2021, has an ICE Brent Index strike price of $36.00 per barrel, and is settled monthly. Therefore, DenizBank is required to make a payment to us if the average monthly ICE Brent Index price is less than $36.00 per barrel, and we are required to make a payment to DenizBank if the average monthly ICE Brent Index price is greater than $36.00 per barrel.

Türkiye Petrol Rafinerileri A.Ş. (“TUPRAS”), a privately-owned oil refinery in Turkey, purchases substantially all of our crude oil production. The price of substantially all of the oil delivered pursuant to the purchase and sale agreement with TUPRAS is tied to Arab Medium oil prices adjusted upward based on an API adjustment, Suez Canal tariff costs, and freight charges. Recently, there has been a significant widening of the differential between the ICE Brent Index price and our realized oil prices. In 2018 and 2019, the average monthly differential between the ICE Brent Index Price and our realized oil prices was $2.44 and $0.17 per barrel, respectively. In April and May 2020, the average monthly differential between the ICE Brent Index Price and our realized oil prices was $6.90 and $8.34 per barrel, respectively. The widening of the differential between ICE Brent Index Price and our realized oil prices has rendered our hedges less effective, resulting in significantly lowered revenues. This differential may expand or contract in the future.

The price of the oil delivered pursuant to the purchase and sale agreement with TUPRAS is determined under the Petroleum Market Law No. 5015 under the laws of the Republic of Turkey. In November 2019, TUPRAS filed a lawsuit seeking restitution from us for alleged overpayments resulting from a February 2019 amendment to the Turkish domestic crude oil pricing formula under Petroleum Market Law No. 5015 (the “Pricing Amendment”). TUPRAS also claimed that the Pricing Amendment violates the Constitution of the Republic of Turkey and seeks to have the Pricing Amendment cancelled. Additionally, in April 2020, TUPRAS notified us that it intends to extend payment terms for oil purchases by 60 days. The outcome of the TUPRAS lawsuit and negotiations regarding the extension of payment terms is uncertain; however, a conclusion of the lawsuit in TUPRAS’s favor or an extension of payment terms would reduce or delay our cash flow and decrease our cash balances.

In the second quarter of 2020, we borrowed approximately $626,000 pursuant to the U.S. Payment Protection Program (the “PPP”) to cover certain payroll, benefit, and rent expenses. We have forecast that amounts borrowed or received pursuant to the PPP will be forgiven for cash flow purposes. New guidance on the criteria for forgiveness continues to be released. Additionally, in the second quarter of 2020, the Turkish government passed legislation permitting employers to reduce the working hours of employees, reducing payroll and benefit expenses, through the end of June 2020. The projected reduction in payroll and benefit expenses due to this legislation is approximately $360,000.  

As of March 31, 2020, we had $10.6 million of outstanding principal under the 2019 Term Loan. The 2019 Term Loan is payable in one monthly installment of $0.6 million in June 2020 and seven monthly installments of $1.4 million plus accrued interest from July 2020 through the maturity date in February 2021. In addition, dividends on our Series A Preferred Shares are payable quarterly at our election in cash, common shares, or a combination of cash and common shares at an annual dividend rate of 12.0% of the liquidation preference if paid in cash or 16.0% of the liquidation preference if paid in common shares. If paid partially in cash and partially in common shares, the dividend rate on the cash portion is 12.0%, and the dividend rate on the common share portion is 16.0%. In order to conserve cash, we elected to pay the second dividend in 2020 in common shares.

As of the date hereof, based on cash on hand and projected future cash flow from operations, our current liquidity position is severely constrained and is forecast to worsen during 2020 as revenues are insufficient to meet our ordinary course expenditures and debt obligations. Based on our current cash flow forecasts, we may be unable to pay the scheduled monthly installments on the 2019 Term Loan in the fourth quarter of 2020 unless we can increase revenues, obtain additional financing, or restructure our current obligations. To date, we have been unable to restructure our current obligations or obtain additional financing to alleviate these liquidity issues. As a result, substantial doubt exists regarding our ability to continue as a going concern. Our management is actively pursuing improving our working capital position in order to remain a going concern for the foreseeable future.  

Management believes the going concern assumption to be appropriate for these consolidated financial statements.  If the going concern assumption was not appropriate, adjustments would be necessary to the carrying values of assets and liabilities, reported revenues and expenses and in the balance sheet classifications used in these consolidated financial statements.

3. Recent accounting pronouncements

In June 2016, the Financial Accounting Standards Board (“FASB”) issued ASU 2016-13, Financial Instruments - Credit Losses (“ASU 2016-13”). ASU 2016-13 changes the impairment model for most financial assets and certain other instruments, including

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trade and other receivables, held-to-maturity debt securities and loans, and requires entities to use a new forward-looking expected loss model that will result in the earlier recognition of allowance for losses. This update is effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. Early adoption is permitted for a fiscal year beginning after December 15, 2018, including interim periods within that fiscal year. Entities will apply the standard’s provisions as a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is adopted. We are currently assessing the potential impact of ASU 2016-13 on our consolidated financial statements and results of operations.

In November 2018, the FASB ASU 2018-19, Codification Improvements to Topic 326, Financial Instruments-Credit Losses. This update clarifies that receivables arising from operating leases are not in scope of this topic, but rather Topic 842, Leases. This update will be effective for financial statements issued for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. This update will be applied through a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is effective. We adopted this standard effective January 1, 2020. The adoption of this update had no impact on our consolidated financial statements and results of operations.

In December 2019, the FASB issued ASU 2019-12, Income Taxes (Topic 740) - Simplifying the Accounting for Income Taxes. This update removes certain exceptions to the general principles in Topic 740 and provides clarifications related to certain franchise taxes, transactions with a government that result in a step-up in the tax basis of goodwill, allocation of current and deferred income tax expense and the annual effective tax rate.  This update is effective January 1, 2021.  We are currently assessing the potential impact of this update on our consolidated financial statements and results of operations.

We have reviewed other recently issued, but not yet adopted, accounting standards in order to determine their effects, if any, on our consolidated results of operations, financial position and cash flows. Based on that review, we believe that none of these pronouncements will have a significant effect on current or future earnings or operations.

4. Series A Preferred Shares

Series A Preferred Shares

As of March 31, 2020 and 2019, we had 921,000 outstanding Series A Preferred Shares. The Series A Preferred Shares contain a substantive conversion option, are mandatorily redeemable and convert into a fixed number of common shares. As a result, under U.S. GAAP, we have classified the Series A Preferred Shares within mezzanine equity in our consolidated balance sheets. As of March 31, 2020, there were $5.0 million of Series A Preferred Shares and $41.1 million of Series A Preferred Shares – related party outstanding (See Note 15. “Related party transactions”).

Pursuant to the Certificate of Designations for the Series A Preferred Shares (as amended to date, the “Certificate of Designations”), each Series A Preferred Share may be converted at any time, at the option of the holder, into 45.754 common shares (which is equal to an initial conversion price of approximately $1.0928 per common share and is subject to customary adjustments for stock splits, stock dividends, recapitalizations or other fundamental changes).

If not converted sooner, on November 4, 2024, we are required to redeem the outstanding Series A Preferred Shares in cash at a price per share equal to the liquidation preference plus accrued and unpaid dividends. At any time on or after November 4, 2020, we may redeem all or a portion of the Series A Preferred Shares at the redemption prices listed below (expressed as a percentage of the liquidation preference amount per share) plus accrued and unpaid dividends to the date of redemption, if the closing sale price of the common shares equals or exceeds 150% of the conversion price then in effect for at least 10 trading days (whether or not consecutive) in a period of 20 consecutive trading days, including the last trading day of such 20 trading day period, ending on, and including, the trading day immediately preceding the business day on which we issue a notice of optional redemption. The redemption prices for the 12-month period starting on the dates below are:

 

Additionally, upon the occurrence of a change of control (as defined in the Certificate of Designations), we are required to offer to redeem the Series A Preferred Shares within 120 days after the first date on which such change of control occurred, for cash at a redemption price equal to the liquidation preference per share, plus any accrued and unpaid dividends.  A change of control excludes a transaction with Mr. Mitchell, his family members, and their affiliates.  

Dividends on the Series A Preferred Shares are payable quarterly at our election in cash, common shares or a combination of cash and common shares at an annual dividend rate of 12.0% of the liquidation preference if paid all in cash or 16.0% of the liquidation preference if paid in common shares. If paid partially in cash and partially in common shares, the dividend rate on the cash portion is

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12.0%, and the dividend rate on the common share portion is 16.0%. Dividends are payable quarterly on March 31, June 30, September 30, and December 31 of each year, except for the first dividend payable after March 31, 2020, which dividend will be payable thirty business days following our public filing of this Quarterly Report on Form 10-Q. The holders of the Series A Preferred Shares also are entitled to participate pro-rata in any dividends paid on the common shares on an as-converted-to-common shares basis. For the three months ended March 31, 2020 and 2019, we paid $1.3 million in cash dividends on the Series A Preferred Shares, which is recorded in our consolidated statements of comprehensive (loss) income under the caption “Interest and other expense”. In order to conserve cash, we have elected to pay the second dividend in 2020 in common shares.  

Except as required by Bermuda law, the holders of Series A Preferred Shares have no voting rights, except that for so long as at least 400,000 Series A Preferred Shares are outstanding, the holders of the Series A Preferred Shares voting as a separate class have the right to elect two directors to our Board of Directors. For so long as between 80,000 and 399,999 Series A Preferred Shares are outstanding, the holders of the Series A Preferred Shares voting as a separate class have the right to elect one director to our Board of Directors. Upon less than 80,000 Series A Preferred Shares remaining outstanding, any directors elected by the holders of Series A Preferred Shares shall immediately resign from our Board of Directors.

The Certificate of Designation also provides that without the approval of the holders of a majority of the outstanding Series A Preferred Shares, we will not issue indebtedness for money borrowed or other securities which are senior to the Series A Preferred Shares in excess of the greater of (i) $100 million or (ii) 35% of our PV-10 of proved reserves as disclosed in our most recent independent reserve report filed or furnished by us on EDGAR.

5. Property and equipment

Oil and natural gas properties

The following table sets forth the capitalized costs under the successful efforts method for our oil and natural gas properties as of:

 

 

At March 31, 2020 and December 31, 2019, we excluded $0.3 million and $0.2 million, respectively, from the depletion calculation for proved development wells currently in progress and for costs associated with fields currently not in production.

At March 31, 2020, the capitalized costs of our oil and natural gas properties, net of accumulated depletion, included $3.4 million relating to acquisition costs of proved properties, which are being depleted by the unit-of-production method using total proved reserves, and $56.8 million relating to well costs and additional development costs, which are being depleted by the unit-of-production method using proved developed reserves.

At December 31, 2019, the capitalized costs of our oil and natural gas properties included $5.0 million relating to acquisition costs of proved properties, which are being amortized by the unit-of-production method using total proved reserves, and $63.8 million relating to well costs and additional development costs, which are being amortized by the unit-of-production method using proved developed reserves.

Impairments of proved properties and impairment of exploratory well costs

Proved oil and natural gas properties are reviewed for impairment when events and circumstances indicate the carrying value of such properties may not be recoverable. We primarily use Level 3 inputs to determine fair value, including but not limited to, estimates of proved reserves, future commodity prices, the timing and amount of future production and capital expenditures and discount rates commensurate with the risk reflective of the lives remaining for the respective oil and natural gas properties.

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During the three months ended March 31, 2020, we recorded $2.1 million of exploratory dry-hole costs and $18.2 million of impairment of proved properties, which are primarily measured using Level 3 inputs.  During the three months ended March 31, 2019, we recorded $5.1 million of exploratory dry-hole costs, which are primarily measured using Level 3 inputs.  

Capitalized cost greater than one year

As of March 31, 2020, there were no exploratory well costs greater than one year.

Equipment and other property

The historical cost of equipment and other property, presented on a gross basis with accumulated depreciation, is summarized as follows:

 

 

At March 31, 2020, in addition to the above, we have classified $3.8 million of inventory as a current asset, which represents our expected inventory consumption during the next twelve months. We classify our remaining materials and supply inventory as a long-term asset because such materials will ultimately be classified as a long-term asset when the material is used in the drilling of a well.

At March 31, 2020 and December 31, 2019, we excluded $10.4 million and $10.3 million of inventory, respectively, from depreciation as the inventory had not been placed into service.

6. Asset retirement obligations

The following table summarizes the changes in our asset retirement obligations (“ARO”) for the three months ended March 31, 2020 and for the year ended December 31, 2019:

 

 

Our ARO is measured using primarily Level 3 inputs. The significant unobservable inputs to this fair value measurement include estimates of plugging costs, remediation costs, inflation rate and well life. The inputs are calculated based on historical data as well as current estimated costs.

 

During the three months ended March 31, 2020 and 2019, we recorded accretion expense of $0.1 million and $0.1 million, respectively.

7. Derivative instruments

We use derivative instruments to manage certain risks related to commodity prices and foreign currency exchange rates. The use of derivative instruments for risk management is covered by operating policies and is closely monitored by our senior management. We do not hold any derivatives for speculative purposes and do not use derivatives with leveraged or complex features. We have not

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designated the derivative contracts as hedges for accounting purposes, and accordingly, we record the derivative contracts at fair value and recognize changes in fair value in earnings as they occur.

To the extent that a legal right of offset exists, we net the value of our derivative contracts with the same counterparty in our consolidated balance sheets. All of our oil derivative contracts are settled based upon Brent crude oil pricing. We recognize gains and losses related to these contracts on a fair value basis in our consolidated statements of operations and comprehensive loss under the caption “(Loss) gain on derivative contracts.” Settlements of derivative contracts are included in operating activities on our consolidated statements of cash flows under the caption “Cash settlement on derivative contracts.”

On March 9, 2020, we unwound our three-way collar contract with DenizBank, which hedged approximately 1,000 Bbl/d of our oil production in Turkey. The three-way collar contract had a Brent floor of $55.00, a Brent ceiling of $72.90, and a Brent long call of $80.00, and was in place through April 30, 2020. We also unwound our swap contract with DenizBank, which hedged approximately 1,000 Bbl/d of our oil production in Turkey. The swap contract had a Brent strike price of $60.30 and was in place through December 31, 2020. In connection with these transactions, we received approximately $6.5 million. We used these proceeds to pay down the 2019 Term Loan to reduce our future interest expense.  

At March 31, 2020, we did not have any commodity or foreign exchange derivative contracts.  At December 31, 2019, we had outstanding commodity derivative contracts with respect to our future crude oil production as set forth in the tables below:

Fair Value of Derivative Instruments as of December 31, 2019

During the three months ended March 31, 2020 and 2019, we recorded a net gain on derivative contracts of $7.5 million and a net loss of $0.1 million, respectively.

Balance sheet presentation

The following table summarizes both: (i) the gross fair value of our derivative instruments by the appropriate balance sheet classification even when the derivative instruments are subject to netting arrangements and qualify for net presentation in our consolidated balance sheets at December 31, 2019, and (ii) the net recorded fair value as reflected on our consolidated balance sheet at December 31, 2019.  At March 31, 2020 we did not have any commodity or foreign exchange derivative contracts.

 

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On April 3, 2020, we entered into a new swap contract DenizBank, which hedged approximately 2,000 barrels of oil per day. The swap contract is in place from May 2020 through February 2021, has an ICE Brent Index strike price of $36.00 per barrel, and is settled monthly. Therefore, DenizBank is required to make a payment to us if the average monthly ICE Brent Index price is less than $36.00 per barrel, and we are required to make a payment to DenizBank if the average monthly ICE Brent Index price is greater than $36.00 per barrel.

 

On May 20, 2020, we entered into foreign exchange forward contracts to hedge against currency fluctuations between the TRY and USD. The forward contract settlement dates are from June through August for $1.0 million at a strike price of 6.84 TRY to $1.00 USD.

 

8. Loans payable

As of the dates indicated, our third-party debt consisted of the following:

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On August 23, 2016, the Turkish branch of TransAtlantic Exploration Mediterranean International Pty Ltd (“TEMI”) entered into a Credit Agreement (the “Credit Agreement”) with DenizBank. The Credit Agreement is a master agreement pursuant to which DenizBank may make loans to TEMI from time to time pursuant to additional loan agreements.

On August 31, 2016, we and DenizBank entered into additional agreements with respect to up to $20.0 million of non-cash facilities, including guarantee letters and treasury instruments for future hedging transactions.

2017 Term Loan

On November 17, 2017, DenizBank entered into a $20.4 million term loan (the “2017 Term Loan”) with TEMI under the Credit Agreement.

The 2017 Term Loan bore interest at a fixed rate of 6.0% (plus 0.3% for Banking and Insurance Transactions Tax per the Turkish government) per annum. The 2017 Term Loan had a grace period which bore no interest or payments due until July 2018. Thereafter, the 2017 Term Loan was payable in one monthly installment of $1.38 million, nine monthly installments of $1.2 million each through April 2019 and thereafter in eight monthly installments of $1.0 million each through December 2019, with the exception of one monthly installment of $1.2 million occurring in October 2019.

On December 30, 2019, we repaid the 2017 Term Loan in full in accordance with its terms.

2018 Term Loan

On May 28, 2018, DenizBank entered into a $10.0 million term loan (the “2018 Term Loan”) with TEMI under the Credit Agreement.

The 2018 Term Loan bore interest at a fixed rate of 7.25% (plus 0.3% for Banking and Insurance Transactions Tax per the Turkish government) per annum. The 2018 Term Loan had a grace period through July 2018 during which no payments were due. Thereafter, accrued interest on the 2018 Term Loan was payable monthly and the principal on the 2018 Term Loan was payable in five monthly installments of $0.2 million each through December 2018, four monthly installments of $0.5 million each through April 2019, four monthly installments of $1.0 million each through August 2019, and four monthly installments of $0.75 million each through December 2019.

On December 30, 2019, we repaid the 2018 Term Loan in full in accordance with its terms.

2019 Term Loan

On February 22, 2019, DenizBank entered into a $20.0 million term loan (the “2019 Term Loan”) with TEMI under the Credit Agreement.

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The 2019 Term Loan bears interest at a fixed rate of 7.5% (plus 0.375% for Banking and Insurance Transactions Tax per the Turkish government) per annum. The 2019 Term Loan had a grace period through December 2019 during which no payments were due. Thereafter, accrued interest on the 2019 Term Loan was payable monthly, and the principal on the 2019 Term Loan was payable in 14 monthly installments of $1.4 million each.

On March 9, 2020, we unwound our three-way collar contract with DenizBank and received approximately $6.5 million in proceeds, which we used to pay down the 2019 Term Loan.  As part of the pay down, DenizBank extended a grace period for principal repayments until June 29, 2020, at which time we will resume principal payments for one monthly installment in June 2020 of $0.6 million and seven monthly installments of $1.4 million beginning in July 2020.The 2019 Term Loan matures in February 2021. Amounts repaid under the 2019 Term Loan may not be reborrowed, and early repayments under the 2019 Term Loan are subject to early repayment fees. The 2019 Term Loan is guaranteed by Amity Oil International Pty Ltd (“Amity”), Talon Exploration, Ltd. (“Talon Exploration”), DMLP, Ltd. (“DMLP”), and TransAtlantic Turkey, Ltd. (“TransAtlantic Turkey”).

The 2019 Term Loan contains standard prohibitions on the activities of TEMI as the borrower, including prohibitions on encumbering or creating restrictions or limitations on all or a part of its assets, revenues, or properties, giving guaranties or sureties, selling assets or transferring revenues, dissolving, liquidating, merging, or consolidating, incurring additional debt, paying dividends, making certain investments, undergoing a change of control, and other similar matters. In addition, the 2019 Term Loan prohibits Amity, Talon Exploration, DMLP, and TransAtlantic Turkey from incurring additional debt. An event of default under the 2019 Term Loan includes, among other events, failure to pay principal or interest when due, breach of certain covenants, representations, warranties, and obligations, bankruptcy or insolvency, and the occurrence of a material adverse effect.

The 2019 Term Loan is secured by a pledge of (i) the stock of TEMI, DMLP, TransAtlantic Turkey, and Talon Exploration, (ii) substantially all of the assets of TEMI, (iii) certain Gundem real estate and Muratli real estate owned by Gundem (as defined in Note 15. “Related party transactions”), (iv) certain Diyarbakir real estate owned 80% by Mr. Mitchell and 20% by Mr. Uras, and (v) certain Ankara real estate owned 100% by Mr. Uras. In addition, TEMI assigned its Turkish collection accounts and its receivables from the sale of oil to DenizBank as additional security for the 2019 Term Loan.   

At March 31, 2020, we had $10.6 million outstanding under the 2019 Term Loan and no availability, and we were in compliance with the covenants in the 2019 Term Loan.

For the three months ended March 31, 2020 and 2019, we recorded interest expense related to the term loans of $0.3 million and $0.3 million, respectively.

9. Leases

Operating and financing leases

We lease office space in Dallas, Texas, Bulgaria and Turkey.  We also lease apartments, vehicles and operations yards in Turkey.    The terms of our lease agreements generally range from one to five years, with some containing options to renew or cancel. We determine if an arrangement meets the definition of a lease at inception, at which time we also perform an analysis to determine whether the lease qualifies as an operating or financing lease.

Our operating and financing leases are included in other assets and accrued liabilities (current and long-term) on our consolidated balance sheet.  Lease expense for our operating leases is recognized in our consolidated statements of comprehensive (loss) income under the caption “General and administrative”.  Lease expense for our operating leases for our operations yards in Turkey is recognized in our consolidated statements of comprehensive (loss) income under the caption “Production”.

Lease right-of-use assets and lease liabilities are measured using the present value of future minimum lease payments over the lease term at commencement date. The right-of-use asset also includes any lease payments made on or before the commencement date of the lease, less any lease incentives received. As the rate implicit in the lease is not readily determinable in our leases, we use our incremental borrowing rates based on the information available at the lease commencement date in determining the present value of lease payments.

For leases with an initial non-cancelable lease term of less than one year and no option to purchase, we have elected not to recognize the lease on our consolidated balance sheets and instead recognize lease payments on a straight-line basis over the lease term.

Operating lease costs were comprised of the following:

 

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Future non-cancelable minimum lease payments under our operating lease commitments as of March 31, 2020 are as follows for each of the next five years and thereafter:

 

As of March 31, 2020, the weighted average remaining lease term in years is 3.7 years and the weighted average discount rate used was 7.55%.  

Future non-cancelable minimum lease payments under our operating lease commitments as of December 31, 2019 were as follows for each of the next five years and thereafter:

 

 

10. Contingencies relating to production leases and exploration permits

Selmo

We are involved in litigation with persons who claim ownership of a portion of the surface at the Selmo oil field in Turkey. These cases are being vigorously defended by TEMI and Turkish governmental authorities. We do not have enough information to estimate the potential additional operating costs we would incur in the event the purported surface owners’ claims are ultimately successful. Any adjustment arising out of the claims will be recorded when it becomes probable and measurable.

Bulgaria

During 2012, we were notified that the Bulgarian government may seek to recover approximately $2.0 million in contractual obligations under our Aglen exploration permit work program. Due to the Bulgarian government’s January 2012 ban on fracture stimulation and related activities, a force majeure event under the terms of the exploration permit was recognized by the Bulgarian government. Although we invoked force majeure, we recorded $2.0 million in general and administrative expense relating to our Aglen exploration permit during 2012 for this contractual obligation.

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In October 2015, the Bulgarian Minister of Energy filed a suit in the Sofia City Court against Direct Petroleum Bulgaria EOOD (“Direct Bulgaria”), claiming $200,000 in liquidated damages for Direct Bulgaria’s alleged failure to fulfill its obligations under the Aglen exploration permit work program. In May 2018, the Sofia City Court concluded that Direct Bulgaria did not fail to fulfill its obligations under the Aglen exploration permit work program as Direct Bulgaria received a force majeure event recognition as a result of a fracture stimulation ban in 2012, imposed by the Bulgarian Parliament, which force majeure event had not been terminated before the expiry of Direct Bulgaria’s obligations under the Aglen exploration permit work program. Additionally, the Sofia City Court concluded that, even if Direct Bulgaria had failed to fulfill its obligations under the Aglen exploration permit work program, the Bulgarian Minister of Energy failed to file suit within the three-year limitation period. Therefore, the Sofia City Court dismissed all claims of the Bulgarian Minister of Energy and ordered the Bulgarian Minister of Energy to pay Direct Bulgaria’s attorney’s fees and legal costs for court experts. In June 2018, the Bulgarian Minister of Energy filed an appeal in the Sofia Court of Appeal. In November 2018, the Sofia Court of Appeal concluded that the judgement of the Sofia City Court was correct and, therefore, dismissed the Bulgarian Minister of Energy’s appeal. In January 2019, the Bulgarian Minister of Energy filed an appeal in the Supreme Court of Cassation.  The Supreme Court of Cessation held a court hearing on October 21, 2019. A ruling was issued on March 10, 2020, by virtue of which the Supreme Court of Cessation decided that the appeal of the Bulgarian Minister of Energy in its substance is inadmissible. The Bulgarian Minister of Energy has no further rights to appeal.

 

TUPRAS

 

We sell all of our Southeastern Turkey oil to TUPRAS pursuant to a domestic crude oil purchase and sale agreement between TUPRAS and TEMI. The price of the oil delivered pursuant to the purchase and sale agreement is determined under the Petroleum Market Law No. 5015 under the laws of the Republic of Turkey. In February 2019, Turkey entered into the Pricing Amendment to change the statutory pricing formula for purchases of Turkish domestic crude oil.

In November 2019, TUPRAS filed a lawsuit against us, and filed similar lawsuits against other domestic oil producers, in the Batman 4th Civil Court of First Instance seeking restitution from TEMI for alleged overpayments resulting from the implementation of the Pricing Amendment plus interest thereon. In addition, TUPRAS claimed that the Pricing Amendment violates the Constitution of the Republic of Turkey and seeks to have the Pricing Amendment cancelled. TEMI is vigorously defending against these allegations. Any adjustment arising out of the claims will be recorded when it becomes probable and measurable.

11. Shareholders’ equity

Restricted stock units

We recorded share-based compensation expense of $0.1 million and $0.1 million for awards of restricted stock units (“RSUs”) for the three months ended March 31, 2020 and 2019, respectively.

As of March 31, 2020, we had approximately $0.3 million of unrecognized compensation expense related to unvested RSUs, which is expected to be recognized over a weighted average period of 0.7 years.

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Earnings per share

We account for earnings per share in accordance with ASC Subtopic 260-10, Earnings Per Share (“ASC 260-10”). ASC 260-10 requires companies to present two calculations of earnings per share: basic and diluted. Basic earnings per common share for the three months ended March 31, 2020 and 2019 equals net loss divided by the weighted average shares outstanding during the periods. Weighted average shares outstanding are equal to the weighted average of all shares outstanding for the period, excluding unvested RSUs. Diluted earnings per common share for the three months ended March 31, 2020 and 2019 are computed in the same manner as basic earnings per common share after assuming the issuance of common shares for all potentially dilutive common share equivalents, which includes RSUs and preferred shares, whether exercisable or not. For the three months ended March 31, 2020, there were no dilutive securities included in the calculation of diluted earnings per share.

The following table presents the basic and diluted earnings per common share computations:

 

12. Segment information

In accordance with ASC 280, Segment Reporting (“ASC 280”), we have two reportable geographic segments: Turkey and Bulgaria. Summarized financial information from operations concerning our geographic segments is shown in the following table:

 

13. Financial instruments

Interest rate risk

We are exposed to interest rate risk as a result of our variable rate short-term cash holdings.

Foreign currency risk

We have underlying foreign currency exchange rate exposure. Our currency exposures primarily relate to transactions denominated in the Bulgarian Lev, the European Union Euro, and the TRY. We are also subject to foreign currency exposures resulting from translating the functional currency of our subsidiary financial statements into the USD reporting currency. At March 31, 2020, we had 23.2 million TRY (approximately $3.6 million) in cash and cash equivalents, which exposes us to exchange rate risk based on fluctuations in the value of the TRY. At March 31, 2020, we were a party to foreign exchange derivative contracts (See Note 7. “Derivative instruments”).

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Commodity price risk

We are exposed to fluctuations in commodity prices for oil and natural gas. Commodity prices are affected by many factors, including, but not limited to, supply and demand. At March 31, 2020, we were not party to any commodity derivative contracts.

Concentration of credit risk

The majority of our receivables are within the oil and natural gas industry, primarily from our industry partners and from government agencies. Included in receivables are amounts due from Turkiye Petrolleri Anonim Ortakligi (“TPAO”), the national oil company of Turkey, Zorlu Dogal Gaz Ithalat Ihracat ve Toptan Ticaret A.S. (“Zorlu”), a privately owned natural gas distributor in Turkey, and TUPRAS, which purchase the majority of our oil and natural gas production. The receivables are not collateralized. To date, we have experienced minimal bad debts and have no allowance for doubtful accounts for TUPRAS. The majority of our cash and cash equivalents are held by four financial institutions in the United States and Turkey.

Fair value measurements

Cash and cash equivalents, restricted cash, accounts receivable, accounts payable, accrued liabilities and our loans payable were each estimated to have a fair value approximating the carrying amount at March 31, 2020 and December 31, 2019, due to the short maturity of those instruments.

The following table summarizes the valuation of our financial liabilities as of March 31, 2020:

 

The following table summarizes the valuation of our financial liabilities as of December 31, 2019:

 

We remeasure our derivative contracts on a recurring basis, with changes flowing through earnings. At March 31, 2020 and December 31, 2019, the fair values of the 2019 Term Loan were estimated using a discounted cash flow analysis based on unobservable Level 3 inputs, including our own credit risk associated with the loans payable.

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14. Asset divestiture

On February 24, 2020, we sold the shares in our wholly-owned subsidiary Petrogas Petrol Gaz ve Petrokemya Urunleri Insaat Sanayive Ticaret A.S. (“Petrogas”), which held the Edirne, Dogu Adatepe, Adatepe, and Gocerler production leases (the “Petrogas Leases”) and 14 employees, to Reform Ham Petrol Dogal Gaz Arama Uretim Sanayi ve Ticaret A.S. (“Reform”) in exchange for $1.5 million and a release of all plugging and abandonment obligations for 65 wells on the Petrogas leases and certain former leases.

 

For the three months ended March 31, 2020, we recorded a net loss of $10.1 million on the sale of Petrogas.  The loss primarily related to the reclassification of the accumulated foreign currency translation adjustment that was realized into earnings from accumulated other comprehensive loss within shareholders’ equity and presented below:

 

15. Related party transactions

The following table summarizes related party accounts receivable and accounts payable as of the dates indicated:

Services transactions

We are a party to a Service Agreement (as amended, the “Service Agreement”) with Longfellow Energy, LP (“Longfellow”), Viking Drilling, LLC (“Viking Drilling”), Riata Management, LLC (“Riata”), LFN Holdco LLC (“LFN”), Red Rock Minerals, LP (“RRM”), Red Rock Minerals II, LP (“RRM II”), Red Rock Advisors, LLC (“RRA”), Production Solutions International Limited (“PSIL”), and NexLube Operating, LLC (“NexLube”) and their subsidiaries (collectively, the “Riata Entities”), under which we and the Riata Entities agreed to provide technical and administrative services to each other from time to time on an as-needed basis. Under the terms of the Service Agreement, the Riata Entities agree to provide us upon our request certain computer services, payroll and benefits services, insurance administration services, and entertainment services, and we and the Riata Entities agree to provide to each other certain management consulting services, oil and natural gas services, and general accounting services (collectively, the “Services”). Under the terms of the Service Agreement, we pay, or are paid, for the actual cost of the Services rendered plus the actual cost of reasonable expenses on a monthly basis. We or any Riata Entity may terminate the Service Agreement at any time by providing advance notice of termination to the other parties.

As of March 31, 2020, we had $0.3 million of outstanding receivables and $0.2 million of outstanding payables pursuant to the Service Agreement.

On March 3, 2016, Mr. Mitchell closed a transaction whereby he sold his interests in Viking Services B.V. (“Viking Services”), the beneficial owner of Viking International Limited (“Viking International”), Viking Petrol Sahasi Hizmetleri A.S. (“VOS”) and Viking Geophysical Services Ltd. (“Viking Geophysical”), to a third party. As part of the transaction, Mr. Mitchell acquired certain equipment used in the performance of stimulation, wireline, workover and similar services, which equipment is owned and operated by Production Solutions International Petrol Arama Hizmetleri Anonim Sirketi (“PSI”). PSI is beneficially owned by PSIL, which is

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beneficially owned by Dalea Investment Group, LLC, which is controlled by Mr. Mitchell. Consequently, on March 3, 2016, TEMI entered into a master services agreement (the “PSI MSA”) with PSI on substantially similar terms to our then current master services agreements with Viking International, VOS, and Viking Geophysical. Pursuant to the PSI MSA, PSI performs the services on behalf of TEMI and its affiliates. On February 28, 2019, TEMI and PSI entered into an amendment (the “PSI MSA Amendment”) to the PSI MSA, pursuant to which PSI and TEMI agreed to extend the primary term of the PSI MSA to February 26, 2021, with automatic successive renewal terms of one (1) year each, unless terminated by PSI or TEMI by written notice at least sixty (60) days prior to the end of the primary term or any successive renewal term. The master services agreement with each of Viking International, VOS, and Viking Geophysical currently remain in effect.

As of March 31, 2020, we had $0.2 million of outstanding receivables and $5.5 million of outstanding payables pursuant to the PSI MSA.

Office sublease

On August 7, 2018 and effective as of June 14, 2018, TransAtlantic USA entered into a sublease agreement (the “Sublease”) with Longfellow to lease corporate office space located at 16803 North Dallas Parkway, Addison, Texas. The Sublease was approved by the audit committee of the board of directors.

TransAtlantic USA subleases approximately 10,000 square feet of corporate office space in Addison, Texas. The initial lease term under the Sublease commenced on June 14, 2018 (the “Commencement Date”) and expires on June 30, 2020, unless earlier terminated in accordance with the Sublease. From the Commencement Date until June 30, 2019, TransAtlantic USA is required to pay monthly rent of $18,333.33 to Longfellow, plus utilities, real property taxes, and liability insurance (to the extent that TransAtlantic USA does not obtain its own liability insurance). The monthly rent increases by $416.67 for the period commencing June 30, 2019 and ending June 30, 2021.

Pursuant to the Sublease, effective as of June 14, 2018, TransAtlantic USA and Longfellow agreed to terminate the Amended and Restated Office Lease, dated June 26, 2017, by and between TransAtlantic USA and Longfellow.

Dalea Note and Pledge Agreement

On June 13, 2012, we closed the sale of our oilfield services business, which was substantially comprised of our wholly owned subsidiaries, Viking International and Viking Geophysical, to a joint venture owned by Dalea Partners, LP (“Dalea”) and funds advised by Abraaj Investment Management Limited for an aggregate purchase price of $168.5 million, consisting of approximately $157.0 million in cash and a $11.5 million promissory note from Dalea (the “Original Note”). The promissory note bore interest at a rate of 3.0% per annum and was guaranteed by Mr. Mitchell. The promissory note was payable five years from the date of issuance or earlier upon the occurrence of certain specified events.

On April 19, 2016, we entered into a note amendment agreement (the “Note Amendment Agreement”) with Mr. Mitchell and Dalea, pursuant to which Dalea agreed to deliver an amended and restated promissory note (the “Amended Note”) in favor of us, in the principal sum of $7,964,053, which Amended Note would amend and restate that certain Promissory Note, dated June 13, 2012, made by Dalea in favor of us in the principal amount of $11.5 million (the “Original Note”). The Note Amendment Agreement reduced the principal amount of the Original Note to $7,964,053 in exchange for the cancellation of an account payable of approximately $3.5 million (the “Account Payable”) owed by TransAtlantic Albania Ltd. (“TransAtlantic Albania”), our former subsidiary, to Viking International. We have indemnified a third party for any liability relating to the payment of the Account Payable.

Pursuant to the Note Amendment Agreement, on April 19, 2016, we entered into the Amended Note, which amended and restated the Original Note that was issued in connection with our sale of our subsidiaries, Viking International and Viking Geophysical Services, to a joint venture owned by Dalea and Abraaj Investment Management Limited in June 2012. In the Amended Note, we and Dalea acknowledged that (i) while the sale of Dalea’s interest in Viking Services enabled us to take the position that the Original Note was accelerated in accordance with its terms, the principal purpose of including the acceleration events in the Original Note was to ensure that certain oilfield services provided by Viking Services to us would continue to be available to us, and (ii) such services will now be provided pursuant to the PSI MSA. PSI is beneficially owned by PSIL, which is beneficially owned by Dalea Investment Group, LLC, which is controlled by Mr. Mitchell. As a result, the Amended Note revised the events triggering acceleration of the repayment of the Original Note to the following: (i) a reduction of ownership by Dalea (and other controlled affiliates of Mr. Mitchell) of equity interest in PSI to less than 50%; (ii) the sale or transfer by Dalea or PSI of all or substantially all of its assets to any person (a “Transferee”) that does not own a controlling interest in Dalea or PSI and is not controlled by Mr. Mitchell (an “Unrelated Person”), or the subsequent transfer by any Transferee that is not an Unrelated Person of all or substantially all of its assets to an Unrelated Person; (iii) the acquisition by an Unrelated Person of more than 50% of the voting interests of Dalea or PSI; (iv) termination of the PSI MSA other than as a result of an uncured default thereunder by TEMI; (v) default by PSI under the PSI MSA, which default is not remedied within a period of 30 days after notice thereof to PSI; and (vi) insolvency or bankruptcy of PSI. The maturity date of the Amended Note was extended to June 13, 2019. The interest rate on the Amended Note remains at 3.0% per annum and continues to be guaranteed by Mr. Mitchell. The Amended Note contains customary events of default.

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In addition, pursuant to the Note Amendment Agreement, on April 19, 2016, we entered into a pledge agreement (the “Pledge Agreement”) with Dalea, whereby Dalea pledged the $2.0 million principal amount of the 2017 Notes owned by Dalea (the “Dalea Convertible Notes”), including any future securities for which the Dalea Convertible Notes are converted or exchanged, as security for the performance of Dalea’s obligations under the Amended Note. The Pledge Agreement provides that interest payable to Dalea under the Dalea Convertible Notes (or any future securities for which the Dalea Convertible Notes are converted or exchanged) will be credited first against the outstanding principal balance of the Amended Note and, upon full repayment of the outstanding principal balance of the Amended Note, any accrued and unpaid interest on the Amended Note. The Pledge Agreement contains customary events of default. On November 4, 2016, Dalea exchanged $2.0 million of 2017 Notes for 40,000 Series A Preferred Shares.

On February 28, 2019, we and Dalea entered into an amendment (the “Note Amendment”) to the Amended Note (as amended by the Note Amendment, the “Note”), pursuant to which Dalea and we agreed to extend the maturity date of the Note to February 26, 2021 (unless otherwise accelerated in accordance with the terms of the Note).

During the three months ended March 31, 2019, we reduced the principal amount of the Note by $1.0 million for amounts prepaid by Dalea on February 28, 2019 in conjunction with the Note Amendment and by $0.1 million for cash dividends paid on the Series A Preferred Shares.

During the three months ended March 31, 2020, we reduced the principal amount of the Note by $0.1 million for cash dividends paid on the Series A Preferred Shares.

As of March 31, 2020, the amount receivable under the Note was $3.7 million.

Pledge fee agreements

In connection with the pledge of certain Gundem real estate and Muratli real estate to DenizBank as collateral for certain loans, on August 31, 2016, we entered into a pledge fee agreement (the “Gundem Fee Agreement”) with Gundem Turizm Yatirim ve Isletme A.S., predecessor-in-interest to Gundem Yatirim with respect to the Gundem real estate and Muratli real estate pledged as collateral for the Term Loans (“Gundem”). Pursuant to the Gundem Fee Agreement, we pay Gundem a fee equal to 5% per annum of the collateral value of the Gundem real estate and Muratli real estate pledged as collateral for the Term Loans. Pursuant to the Gundem Fee Agreement, the Gundem real estate has a deemed collateral value of $10.0 million and the Muratli real estate has a deemed collateral value of $5.0 million.

In connection with the pledge of the Diyarbakir real estate to DenizBank as collateral for certain loans, on August 31, 2016, we entered into a pledge fee agreement with Messrs. Mitchell and Uras (the “Diyarbakir Fee Agreement”) pursuant to which we pay Mr. Mitchell and Mr. Uras a fee of 5% per annum of the collateral value of the Diyarbakir real estate. Pursuant to the Diyarbakir Fee Agreement, the Diyarbakir real estate has a deemed collateral value of $5.0 million.

Amounts payable to Mr. Mitchell under the Gundem Fee Agreement and the Diyarbakir Fee Agreement are used to reduce the outstanding principal amount of the Amended Note. During the three months ended March 31, 2020, we reduced the principal amount of the Amended Note by $0.2 million for amounts paid under the pledge fee agreements.

16. Subsequent Events

On April 3, 2020, we entered into an oil swap contract with DenizBank to hedge 2,000 Bbl/day of our oil production in Turkey.  The term began on May 1, 2020 and extends through February 28, 2021, with a swap price of $36.00 per barrel.

On April 21, 2020, the special committee of the board of directors (the “Committee”) received an unsolicited offer (the “April Offer”) from a group of our current shareholders affiliated with Mr. Mitchell and his children (collectively, the “Mitchell Group”) to acquire 100% of our outstanding common shares, subject to certain conditions.  The Committee engaged a financial advisor to assist with its review and evaluation of the April Offer and any other offers that might be received. After consultation with our legal and financial advisors, the Committee rejected the April Offer. On May 28, 2020, the Committee received a revised, non-binding offer (the “May Offer”) from the Mitchell Group to acquire 100% of our outstanding common shares, subject to certain conditions. After consultation with our legal and financial advisors, the Committee rejected the May Offer. The Committee continues to engage in discussions with the Mitchell Group. There is no assurance that discussions with the Mitchell Group will result in a sale of the Company or any other transaction.

On May 20, 2020, we entered into foreign exchange forward contracts to hedge against currency fluctuations between the TRY and USD. The forward contract settlement dates are from June through August for $1.0 million at a strike price of 6.84 TRY to $1.00 USD.

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On May 22, 2020, in order to correspond to the revised timing for the filing of this Quarterly Report on Form 10-Q, the holders of the Series A Preferred Shares, unanimously approved Amendment No. 1 to the Certificate of Designations of the Series A Preferred Shares (the “Amendment”). The Amendment revised the definitions for Dividend Payment Date and the Dividend Record Date for the upcoming dividend on the Series A Preferred Shares.

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In this Quarterly Report on Form 10-Q, references to “we,” “our,” “us” or the “Company,” refer to TransAtlantic Petroleum Ltd. and its subsidiaries on a consolidated basis unless the context requires otherwise. Unless stated otherwise, all sums of money stated in this Quarterly Report on Form 10-Q are expressed in USD.

Executive Overview

We are an international oil and natural gas company engaged in acquisition, exploration, development, and production. We have focused our operations in countries that have established, yet underexplored petroleum systems, are net importers of petroleum, have an existing petroleum transportation infrastructure and provide favorable commodity pricing, royalty rates, and tax rates to exploration and production companies. As of March 31, 2020, we held interests in 365,171 and 162,800 net acres of developed and undeveloped oil and natural gas properties in Turkey and Bulgaria, respectively. As of June 22, 2020, approximately 49.9% of our outstanding common shares were beneficially owned by N. Malone Mitchell 3rd, our chief executive officer and chairman of our board of directors. Persons and entities associated with Mr. Mitchell also owned 739,000 Series A Preferred Shares. Mr. Mitchell’s affiliates are currently prohibited from converting any of their Series A Preferred Shares to common shares if such conversion would cause Mr. Mitchell or his affiliates to obtain beneficial ownership in excess of 49.9% of the outstanding common shares; however, Mr. Mitchell, upon 61 days’ prior notice, may increase or decrease such percentage cap.

On April 21, 2020, the Committee received the April Offer from the Mitchell Group to acquire 100% of our outstanding common shares, subject to certain conditions.  The Committee engaged a financial advisor to assist with its review and evaluation of the April Offer and any other offers that might be received. After consultation with our legal and financial advisors, the Committee rejected the April Offer. On May 28, 2020, the Committee received the May Offer from the Mitchell Group to acquire 100% of our outstanding common shares, subject to certain conditions. After consultation with our legal and financial advisors, the Committee rejected the May Offer. The Committee continues to engage in discussions with the Mitchell Group. There is no assurance that discussions with the Mitchell Group will result in a sale of the Company or any other transaction.

On May 22, 2020, in order to correspond to the revised timing for the filing of this Quarterly Report on Form 10-Q, the holders of the Series A Preferred Shares, unanimously approved the Amendment, which revised the definitions for Dividend Payment Date and the Dividend Record Date for the upcoming dividend on the Series A Preferred Shares.

We are a holding company with two operating segments – Turkey and Bulgaria. Our assets consist of our ownership interests in subsidiaries that primarily own assets in Turkey and Bulgaria.

Financial and Operational Performance Summary

The following summarizes our financial and operational performance for the first quarter of 2020:

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First Quarter 2020 Operational Update

Southeastern Turkey

Molla

During 2020, we plan to cointinue our recompletion, workover, and production optimization plans in our producing fields, including Bahar, Yeniev, Goksu, Pinar, Southeast Bahar, Catak, and Karagoz.  Drilling additional wells will be dependent on oil prices.

Bahar Field. In the first quarter of 2020, we started construction of phase II electrification of the Bahar field to replace diesel generated power with gas generated power, which will be distributed to each well in the field. The phase II electrification was completed and operational in the second quarter of 2020.

Goksu Field. We whipstocked the Goksu-4H well in January 2020. The well was re-drilled to a total depth of 5,720 feet. Although we encountered high permeability in the Mardin formation, tests did not indicate commercial quantities of oil.

Arpatepe Field. In the first quarter of 2020, we started implementation of a full field waterflood of the Arpatepe field. We plan to recomplete four wells in the field as water injection wells and one well as a water source well. Additionally, we plan to build a central facility and gathering system to handle increased volumes, however this is subject to change due to budget constraints and partner requests.

Selmo

During 2020, we plan to continue our recompletion, workover, and production optimization operations in the Selmo field.

Bulgaria

We are currently evaluating future activity in Bulgaria.

Planned Operations

We expect our net field capital expenditures for the remainder of 2020 to range between $1.0 million and $1.5 million. We expect net field capital expenditures during 2020 may include between $0.5 million and $1.5 million to implement a waterflood in the Bedinan sandstone in the Arpatepe field and up to $0.5 million for recompletions. Our projected 2020 capital expenditure budget is subject to change.

Significant Accounting Policies and Estimates

Our discussion and analysis of our financial condition and results of operations is based upon our consolidated financial statements, which have been prepared in accordance with U.S. GAAP. The preparation of these consolidated financial statements requires management to make estimates and judgments that affect the reported amounts of assets, liabilities, revenue and expenses, and related disclosures. Our significant accounting policies are described in “Note 3. Significant accounting policies” to our audited consolidated financial statements included in our Annual Report on Form 10-K for the year ended December 31, 2019 and are of particular importance to the portrayal of our financial position and results of operations and require the application of significant judgment by management. These estimates are based on historical experience, information received from third parties, and on various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates under different assumptions or conditions.

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Results of Operations—Three Months Ended March 31, 2020 Compared to Three Months Ended March 31, 2019

Our results of operations for the three months ended March 31, 2020 and 2019 were as follows:

 

Oil and Natural Gas Sales. Total oil and natural gas sales revenues decreased to $8.3 million for the three months ended March 31, 2020 from $18.9 million for the same period in 2019. The decrease was primarily due to a decrease in the average realized price per Boe. Our average price received decreased $31.29 per Boe to $36.71 per Boe for the three months ended March 31, 2019 from $68.00 per Boe for the same period in 2019. The decrease was also due to a decrease in our average daily sales volumes of 584 Boe per day (“Boepd”) for the three months ended March 31, 2020 as compared to the same period in 2019.

Production. Production expenses increased to $3.5 million, or $13.55 per Boe, for the three months ended March 31, 2020 from $2.5 million, or $7.90 per Boe, for the same period in 2019. The increase was primarily due to an increase in contract labor costs and personnel expenses of $0.5 million and an increase in workover expenses of $0.4 million.

Transportation and Processing. Transportation and processing expense decreased to $1.2 million for the three months ended March 31, 2020 from $1.3 million for the same period in 2019. The decrease in transportation expenses was primarily due to the decrease in our average daily sales volumes of 584 Boepd.

Exploration, Abandonment and Impairment. Exploration, abandonment and impairment cost increased to $20.3 million for the three months ended March 31, 2020 from $5.1 million for the same period in 2019. The increase was due to proved property impairments of our Selmo and Bahar fields due to the oil price decline and the exploratory dry hole write-off of the Bati-Yasince well.

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General and Administrative. General and administrative expense decreased to $2.4 million for the three months ended March 31, 2020 from $3.1 million for the same period in 2019. The decrease was primarily due to a $0.7 million decrease in personnel expenses compared to the same period in 2019.

Depletion. Depletion expense decreased to $2.9 million, or $11.08 per Boe, for the three months ended March 31, 2020 from $3.6 million, or $11.29 per Boe, for the same period of 2019. The decrease was primarily due to the devaluation of the TRY to the USD and a decrease in production volumes.

Interest and Other Expense. Interest and other expense decreased to $2.2 million for the three months ended March 31, 2020 from $2.5 million for the same period in 2019. The decrease was due to our lower average debt balances outstanding during the three months ended March 31, 2020 versus the same period in 2019.

Foreign Exchange Loss. We recorded a foreign exchange loss of $0.1 million for the three months ended March 31, 2020 as compared to $1.3 million for the same period in 2019. Foreign exchange gains and losses are primarily unrealized (non-cash) in nature and result from the re-measuring of specific transactions and monetary accounts in a currency other than the functional currency. For example, a USD transaction which occurs in Turkey is re-measured at the period-end to the TRY amount if it has not been settled previously. Generally, a strengthening of the USD relative to the TRY increases our foreign exchange loss. The foreign exchange loss for the three months ended March 31, 2020 was due to a decrease in the value of the TRY compared to the USD.

Gain (Loss) on Derivative Contracts. We recorded a net gain on derivative contracts of $7.5 million for the three months ended March 31, 2020 as compared to a net loss of $0.1 million for the same period in 2019. During the three months ended March 31, 2020, we recorded a $1.0 million gain to mark our currency derivative contracts to their fair value and a $6.5 million gain on settled contracts. During the same period in 2019, we recorded a $0.1 million loss to mark our commodity derivative contracts to their fair value.

Capital Expenditures

For the three months ended March 31, 2020, we incurred $2.9 million in capital expenditures, including seismic and corporate expenditures, as compared to $9.9 million for the same period in 2019.

We expect our net field capital expenditures for the remainder of 2020 to range between $1.0 million and $1.5 million. We expect net field capital expenditures during 2020 to include between $0.5 million and $1.5 million to implement a waterflood in the Bedinan sandstone in the Arpatepe field and up to $0.5 million for recompletions. Our projected 2020 capital expenditure budget is subject to change.

Cash Flows

Net cash provided by operating activities during the three months ended March 31, 2020 was $14.1 million, an increase from net cash provided by operating activities of $4.5 million for the same period in 2019. The increase was primarily due to the changes in our current assets and current liabilities partially offset by a decrease in our revenues.

Net cash used in investing activities during the three months ended March 31, 2020 was $1.6 million, a decrease from net cash used in investing activities of $9.3 million for the same period in 2019. The decrease was primarily due to a decrease in our capital expenditures compared to the same period in 2019.

Net cash used in financing activities during the three months ended March 31, 2020 was $9.4 million, a decrease from net cash provided by financing activities of $15.8 million for the same period in 2019. The change was primarily due to a decrease in our outstanding loan.

Liquidity and Capital Resources

Our primary sources of liquidity for the first quarter of 2020 were our cash and cash equivalents, cash flow from operations and the sale of assets. At March 31, 2020, we had cash and cash equivalents of $12.8 million, $10.6 million in short-term debt, and a working capital surplus of $5.9 million, compared to cash and cash equivalents of $9.7 million, $2.9 million in long-term debt, $17.1 million in short-term debt and a working capital surplus of $2.0 million at December 31, 2019.

In March 2020, crude oil prices declined to approximately $25 per barrel for Brent crude as a result of market concerns about the economic impact from the COVID-19 as well as the ability of OPEC and Russia to agree on a perceived need to implement further production cuts in response to weaker worldwide demand.  Since then, Brent crude prices have rebounded to approximately $39.00 per barrel as of June 12, 2020 and remain volatile and unpredictable. The current futures forward curve for Brent crude indicates that prices may continue at or near current prices for an extended time.

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As a result of the decline in Brent crude prices, the current near term price outlook and resulting lower current and projected cash flows from operations, we have reduced our planned capital expenditures to those necessary for production lease maintenance and those projecting a return on invested capital at current prices. In order to mitigate the impact of reduced prices on our 2020 cash flows and liquidity, we implemented cost reduction measures to reduce our operating costs and general and administrative expenses. In connection therewith, we intend to prioritize funding operating expenditures over general and administrative expenditures, whenever possible.

On March 9, 2020, we unwound our commodity derivative contracts with respect to our future crude oil production. In connection with these transactions, we received $6.5 million. In order to reduce future interest expense, we used these proceeds to pay down the 2019 Term Loan. On April 3, 2020, we entered into a new swap contract with DenizBank, which hedged approximately 2,000 barrels of oil per day. The swap contract is in place from May 2020 through February 2021, has an ICE Brent Index strike price of $36.00 per barrel, and is settled monthly. Therefore, DenizBank is required to make a payment to us if the average monthly ICE Brent Index price is less than $36.00 per barrel, and we are required to make a payment to DenizBank if the average monthly ICE Brent Index price is greater than $36.00 per barrel.

TUPRAS purchases substantially all of our crude oil production. The price of substantially all of the oil delivered pursuant to the purchase and sale agreement with TUPRAS is tied to Arab Medium oil prices adjusted upward based on an API adjustment, Suez Canal tariff costs, and freight charges. Recently, there has been a significant widening of the differential between the ICE Brent Index price and our realized oil prices. In 2018 and 2019, the average monthly differential between the ICE Brent Index Price and our realized oil prices was $2.44 and $0.17 per barrel, respectively. In April and May 2020, the average monthly differential between the ICE Brent Index Price and our realized oil prices was $6.90 and $8.34 per barrel, respectively. The widening of the differential between ICE Brent Index Price and our realized oil prices has rendered our hedges less effective, resulting in significantly lowered revenues. This differential may expand or contract in the future.

The price of the oil delivered pursuant to the purchase and sale agreement with TUPRAS is determined under the Petroleum Market Law No. 5015 under the laws of the Republic of Turkey. In November 2019, TUPRAS filed a lawsuit seeking restitution from us for alleged overpayments resulting from the Pricing Amendment. TUPRAS also claimed that the Pricing Amendment violates the Constitution of the Republic of Turkey and seeks to have the Pricing Amendment cancelled. Additionally, in April 2020, TUPRAS notified us that it intends to extend payment terms for oil purchases by 60 days. The outcome of the TUPRAS lawsuit and negotiations regarding the extension of payment terms is uncertain; however, a conclusion of the lawsuit in TUPRAS’s favor or an extension of payment terms would reduce or delay our cash flow and decrease our cash balances.

In the second quarter of 2020, we borrowed approximately $626,000 pursuant to the PPP to cover certain payroll, benefit, and rent expenses. We have forecast that amounts borrowed or received pursuant to the PPP will be forgiven for cash flow purposes. New guidance on the criteria for forgiveness continues to be released. Additionally, in the second quarter of 2020, the Turkish government passed legislation permitting employers to reduce the working hours of employees, reducing payroll and benefit expenses, through the end of June 2020. The projected reduction in payroll and benefit expenses due to this legislation is approximately $360,000.  

As of March 31, 2020, we had $10.6 million of outstanding principal under the 2019 Term Loan. The 2019 Term Loan is payable in one monthly installment of $0.6 million in June 2020 and seven monthly installments of $1.4 million plus accrued interest from July 2020 through the maturity date in February 2021. In addition, dividends on our Series A Preferred Shares are payable quarterly at our election in cash, common shares, or a combination of cash and common shares at an annual dividend rate of 12.0% of the liquidation preference if paid in cash or 16.0% of the liquidation preference if paid in common shares. If paid partially in cash and partially in common shares, the dividend rate on the cash portion is 12.0%, and the dividend rate on the common share portion is 16.0%. In order to conserve cash, we elected to pay the second dividend in 2020 in common shares.

As of the date hereof, based on cash on hand and projected future cash flow from operations, our current liquidity position is severely constrained and is forecast to worsen during 2020 as revenues are insufficient to meet our ordinary course expenditures and debt obligations. Based on our current cash flow forecasts, we may be unable to pay the scheduled monthly installments on the 2019 Term Loan in the fourth quarter of 2020 unless we can increase revenues, obtain additional financing, or restructure our current obligations. To date, we have been unable to restructure our current obligations or obtain additional financing to alleviate these liquidity issues. As a result, substantial doubt exists regarding our ability to continue as a going concern. Our management is actively pursuing improving our working capital position in order to remain a going concern for the foreseeable future.

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Outstanding Debt and Series A Preferred Shares

2017 Term Loan. On November 17, 2017, DenizBank entered into the 2017 Term Loan under the Credit Agreement. The 2017 Term Loan bore interest at a fixed rate of 6.0% (plus 0.3% for Banking and Insurance Transactions Tax per the Turkish government) per annum. The 2017 Term Loan had a grace period which bore no interest or payments due until July 2018. Thereafter, the 2017 Term Loan was payable in one monthly installment of $1.38 million, nine monthly installments of $1.2 million each through April 2019 and thereafter in eight monthly installments of $1.0 million each through December 2019, with the exception of one monthly installment of $1.2 million occurring in October 2019.

On December 30, 2019 we repaid the 2017 Term Loan in full in accordance with its terms.

2018 Term Loan. On May 28, 2018, DenizBank entered into the 2018 Term Loan under the Credit Agreement. The 2018 Term Loan bore interest at a fixed rate of 7.25% (plus 0.3% for Banking and Insurance Transactions Tax per the Turkish government) per annum. The 2018 Term Loan had a grace period through July 2018 during which no payments were due. Thereafter, accrued interest on the 2018 Term Loan was payable monthly and the principal on the 2018 Term Loan was payable in five monthly installments of $0.2 million each through December 2018, four monthly installments of $0.5 million each through April 2019, four monthly installments of $1.0 million each through August 2019, and four monthly installments of $0.75 million each through December 2019.

On December 30, 2019 we repaid the 2018 Term Loan in full in accordance with its terms.

2019 Term Loan. On February 22, 2019, DenizBank entered into the 2019 Term Loan under the Credit Agreement.

The 2019 Term Loan bears interest at a fixed rate of 7.5% (plus 0.375% for Banking and Insurance Transactions Tax per the Turkish government) per annum. The 2019 Term Loan had a grace period through December 2019 during which no payments were due. Thereafter, accrued interest on the 2019 Term Loan was payable monthly and the principal on the 2019 Term Loan was payable in 14 monthly installments of $1.4 million each.  

On March 9, 2020, we unwound our three-way collar contract with DenizBank and received approximately $6.5 million in proceeds which we used to pay down the 2019 Term Loan.  As part of the pay down, DenizBank extended a grace period for principal repayments until June 29, 2020 at which time we will resume principal payments for one monthly installment in June 2020 of $0.6 million and seven monthly installments of $1.4 million beginning in July 2020. The 2019 Term Loan matures in February 2021. Amounts repaid under the 2019 Term Loan may not be reborrowed, and early repayments under the 2019 Term Loan are subject to early repayment fees. The 2019 Term Loan is guaranteed by Amity, Talon Exploration, DMLP, and TransAtlantic Turkey.

The 2019 Term Loan contains standard prohibitions on the activities of TEMI as the borrower, including prohibitions on encumbering or creating restrictions or limitations on all or a part of its assets, revenues, or properties, giving guaranties or sureties, selling assets or transferring revenues, dissolving, liquidating, merging, or consolidating, incurring additional debt, paying dividends, making certain investments, undergoing a change of control, and other similar matters. In addition, the 2019 Term Loan prohibits Amity, Talon Exploration, DMLP, and Transatlantic Turkey from incurring additional debt. An event of default under the 2019 Term Loan includes, among other events, failure to pay principal or interest when due, breach of certain covenants, representations, warranties, and obligations, bankruptcy or insolvency, and the occurrence of a material adverse effect.

The 2019 Term Loan is secured by a pledge of (i) the stock of TEMI, DMLP, TransAtlantic Turkey, and Talon Exploration, (ii) substantially all of the assets of TEMI, (iii) certain Gundem real estate and Muratli real estate owned by Gundem, (iv) certain Diyarbakir real estate owned 80% by Mr. Mitchell and 20% by Mr. Uras, and (v) certain Ankara real estate owned 100% by Mr. Uras. In addition, TEMI will assigned its Turkish collection accounts and its receivables from the sale of oil to DenizBank as additional security for the 2019 Term Loan.

At March 31, 2020, we had $10.6 million outstanding under the 2019 Term Loan and no availability, and we were in compliance with the covenants in the 2019 Term Loan.  

Series A Preferred Shares. As of March 31, 2020, we had 921,000 Series A Preferred Shares outstanding. The Series A Preferred Shares contain a substantive conversion option, are mandatorily redeemable, and convert into a fixed number of common shares. As a result, under U.S. GAAP, we have classified the Series A Preferred Shares within mezzanine equity in our consolidated balance sheets. As of March 31, 2020, we had $5.0 million of Series A Preferred Shares and $41.1 million of Series A Preferred Shares – related party outstanding (See Note 3. “Series A Preferred Shares”).

Not applicable.

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Evaluation of Disclosure Controls and Procedures

Disclosure controls and procedures are controls and other procedures that are designed to ensure that information required to be disclosed in our reports filed or submitted under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed in our reports filed or submitted under the Exchange Act is accumulated and communicated to management, including our chief executive officer and principal accounting and financial officer, as appropriate to allow timely decisions regarding required disclosure.

As of March 31, 2020, management carried out an evaluation, under the supervision and with the participation of our chief executive officer and principal accounting and financial officer, of the effectiveness of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) of the Exchange Act). Based upon the evaluation, our chief executive officer and principal accounting and financial officer concluded that, as of March 31, 2020, our disclosure controls and procedures were effective at the reasonable assurance level.

There are inherent limitations to the effectiveness of any system of disclosure controls and procedures. Accordingly, even effective disclosure controls and procedures can only provide reasonable assurances of achieving their control objectives.

Changes in Internal Control over Financial Reporting

There were no changes in our internal control over financial reporting that occurred during the quarter ended March 31, 2020 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

 

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PART II. OTHER INFORMATION

During the first quarter of 2020, there were no material developments to the Legal Proceedings disclosed in “Part I, Item 3. Legal Proceedings” in our Annual Report on Form 10-K for the year ended December 31, 2019, other than the developments described below:

Bulgarian Minister of Energy. In October 2015, the Bulgarian Minister of Energy filed a suit in the Sofia City Court against Direct Petroleum Bulgaria EOOD (“Direct Bulgaria”), claiming $200,000 in liquidated damages for Direct Bulgaria’s alleged failure to fulfill its obligations under the Aglen exploration permit work program. In May 2018, the Sofia City Court concluded that Direct Bulgaria did not fail to fulfill its obligations under the Aglen exploration permit work program as Direct Bulgaria received a force majeure event recognition as a result of a fracture stimulation ban in 2012, imposed by the Bulgarian Parliament, which force majeure event had not been terminated before the expiry of Direct Bulgaria’s obligations under the Aglen exploration permit work program. Additionally, the Sofia City Court concluded that, even if Direct Bulgaria had failed to fulfill its obligations under the Aglen exploration permit work program, the Bulgarian Minister of Energy failed to file suit within the three-year limitation period. Therefore, the Sofia City Court dismissed all claims of the Bulgarian Minister of Energy and ordered the Bulgarian Minister of Energy to pay Direct Bulgaria’s attorney’s fees and legal costs for court experts. In June 2018, the Bulgarian Minister of Energy filed an appeal in the Sofia Court of Appeal. In November 2018, the Sofia Court of Appeal concluded that the judgement of the Sofia City Court was correct and, therefore, dismissed the Bulgarian Minister of Energy’s appeal. In January 2019, the Bulgarian Minister of Energy filed an appeal in the Supreme Court of Cassation. The Supreme Court of Cassation held a court hearing on October 21, 2019. A ruling was issued on March 10, 2020, by virtue of which the Supreme Court of Cessation decided that the appeal of the Bulgarian Minister of Energy in its substance is inadmissible. The Bulgarian Minister of Energy has no further rights to appeal.

During the first quarter of 2020, there were no material changes to the risk factors disclosed in our Annual Report on Form 10-K for the year ended December 31, 2019.

None

None.

Not applicable.

None.

 

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Signatures

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

 

 

 

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