TransAtlantic Petroleum Announces Second Quarter 2019 Financial Results and Provides an Operations Update
- Average daily net sales volumes were 2,873 barrels of oil equivalent per day (“BOEPD”) in the second quarter of 2019, as compared to 3,082 BOEPD in the first quarter of 2019 and 2,746 BOEPD in the second quarter of 2018.
- Revenues were
$17.2 millionfor the second quarter of 2019, as compared to $19.0 millionfor the first quarter of 2019 and $18.2 millionfor the second quarter of 2018.
- Operating income was
$6.3 millionfor the second quarter of 2019, as compared to $3.2 millionfor the first quarter of 2019 and $6.9 millionfor the second quarter of 2018.
- Net loss was
$0.01 millionfor the second quarter of 2019, as compared to $3.9 millionfor the first quarter of 2019 and $1.0 millionfor the second quarter of 2018.
- Adjusted EBITDAX was
$10.7 millionfor the second quarter of 2019, as compared to $12.3 millionfor the first quarter of 2019 and $8.7 millionfor the second quarter of 2018.1
- Net debt was
$17.5 millionas of June 30, 2019, as compared to $17.2 millionas of March 31, 2019.2 Bank debt was reduced by $5.7 millionin the second quarter of 2019, and capital expenditures were $6.2 millionfor the second quarter of 2019.
1 Adjusted EBITDAX is a non-GAAP financial measure. See the reconciliation at the end of the press release.
2 Net debt is a non-GAAP financial measure consisting of total debt as reflected on the Company’s balance sheet minus cash and cash equivalents as reflected on the Company’s balance sheet. For
Second Quarter 2019 Results of Operations
|For the Three Months Ended|
|Natural gas (MMCF)||48||50||56|
|Total net sales (MBOE)||261||277||250|
|Average net sales (BOEPD)||2,873||3,082||2,746|
|Realized Commodity Prices:|
|Oil ($/Bbl unhedged)||$||66.57||$||69.00||$||74.10|
|Oil ($/Bbl hedged)||$||66.57||$||69.00||$||66.37|
|Natural gas ($/MCF)||$||5.41||$||5.94||$||4.84|
Total revenues were
Adjusted EBITDAX was
Both the Yeniev-1 and West Yeniev-1 wells continue flowing naturally from the Bedinan formation with little water.
The East Yeniev-1 well was put on production in the first quarter of 2019 and completed in the Mardin formation.
In the second quarter of 2019, the Company drilled the Yeniev-4 well to a total measured depth of 9,520 feet targeting the Bedinan, Hazro, and Mardin formations. The Company successfully recovered approximately 120 feet of core from the Bedinan sandstone, which is currently undergoing analysis to assist in infill development planning and secondary recovery evaluation. The Company plans to commence completion operations in the third quarter of 2019.
The Company plans to spud the Yeniev-5 and Yeniev-6 wells in the third and fourth quarter of 2019, respectively, to test the Mardin, Hazro, and Bedinan formations. The Company expects to core approximately 150 feet of the Mardin formation in the Yeniev-5 well to assist in infill development planning and secondary recovery evaluation.
The Southeast Bahar-1 well was drilled to a total measured depth of 11,000 feet in the second quarter of 2019. Oil shows were observed in the Bedinan and Mardin formations, and oil was swab tested from the Bedinan formation. Completion operations are currently ongoing.
The Company commenced drilling the Bahar-12 well in
The Blackeye-1 well continues to produce at a stable rate with low water cut from the Hazro F4 formation. The Company is evaluating testing additional formations within the well and drilling additional appraisal wells to develop the field.
During the second quarter of 2019, the Company’s application for conversion of the New Molla exploration license into a production lease was approved.
The Company plans to stimulate the Pinar-1 side-track well in the third quarter of 2019. The well is currently producing commercial oil with low productivity from the Bedinan formation.
In the third quarter of 2019, the Company plans to re-enter the Bati-Yasince-1 well and deepen the well to the Hazro formation.
In the third quarter of 2019, the Company plans to recomplete the Arpatepe-2 well as a water injection well and execute the first phase of a water-flood of the Arpatepe field. Subject to the results of the initial phase, the Company intends to expand to full-field flooding in the future.
During the second quarter of 2019, the Company has continued a recompletion, workover, and production optimization campaign in the Selmo field.
Thrace Basin BCGA
The Company continues to evaluate its prospects in the Thrace Basin’s Basin Center Gas Accumulation (“Thrace Basin BCGA”) in light of the recent exploration activity by Valeura Energy Inc. (“Valeura”) with its partner Equinor ASA (formerly Statoil ASA) (“Equinor”) on a license directly adjacent to the Company’s 120,000 net acres in the
In the second quarter of 2019, the Company drilled the Karli-1 well to a total measured depth of 1,289 feet and encountered several shallow gas sand intervals. The Company is currently evaluating completion options.
Valeura and Equinor
According to Valeura and Equinor, in the third quarter of 2018, the Yamalik-1 well was recompleted and was flowing gas, condensate, and water. In the second quarter of 2019, Valeura and Equinor announced that they are developing a plan to re-enter the well in order to isolate a portion of the column to conduct further selective zonal flow testing.
In the first quarter of 2019, Valeura and Equinor announced that the Inanli-1 well was drilled to a total depth of 4,885 meters and encountered 1,615 meters of high net-to-gross sandstone, which they interpreted to contain over-pressured gas. According to Valeura and Equinor, completion operations are ongoing.
In the second quarter of 2019, Valeura and Equinor announced that they drilled the Devepinar-1 appraisal well to a total depth of 4,796 meters after drilling a 1,066-meter gross column of indicated over-pressured gas. According to Valeura and Equinor, the Devepinar-1 appraisal well is designed as a 20-kilometer step-out well to test the lateral extent of the Thrace Basin BCGA.
The Company is currently evaluating future activity in
The Company will host a live webcast and conference call on
A live webcast of the conference call and replay will be available through the Company’s website at www.transatlanticpetroleum.com. To access the webcast and replay, click on “Investors,” select “Events and Presentations,” and click on “Listen to webcast” under the event list. The webcast requires IOS, Microsoft Windows Media Player, or RealOne Player.
A telephonic replay of the call will be available through
Consolidated Statements of Comprehensive Income (Loss) (Unaudited)
|For the Three Months Ended||For the Six Months Ended|
|Costs and expenses:|
|Transportation and processing||1,221||1,138||2,540||2,331|
|Exploration, abandonment and impairment||666||191||5,779||231|
|Seismic and other exploration||108||59||185||218|
|General and administrative||2,690||3,786||5,744||7,123|
|Depreciation, depletion and amortization||3,442||3,276||7,158||7,735|
|Accretion of asset retirement obligations||49||43||101||89|
|Total costs and expenses||10,888||11,297||26,721||23,400|
|Other (expense) income:|
|Interest and other expense||(2,753||)||(2,091||)||(5,231||)||(4,873||)|
|Interest and other income||221||377||395||631|
|Loss on commodity derivative contracts||(323||)||(3,141||)||(433||)||(3,866||)|
|Foreign exchange loss||(115||)||(1,938||)||(1,388||)||(3,996||)|
|Total other expense||(2,970||)||(6,793||)||(6,657||)||(12,104||)|
|Income (loss) before income taxes||3,357||108||2,878||(380||)|
|Income tax expense||(3,366||)||(1,114||)||(6,789||)||(2,401||)|
|Other comprehensive loss:|
|Foreign currency translation adjustment||(416||)||(9,109||)||(4,642||)||(11,452||)|
|Net loss per common share|
|Basic net loss per common share||$||(0.00||)||$||(0.02||)||$||(0.07||)||$||(0.06||)|
|Weighted average common shares outstanding||52,529||50,420||52,506||50,397|
|Diluted net loss per common share||$||(0.00||)||$||(0.02||)||$||(0.07||)||$||(0.06||)|
|Weighted average common and common equivalent shares outstanding||52,529||50,420||52,506||50,397|
Summary Consolidated Statements of Cash Flows (Unaudited)
(in thousands of
|For the Six Months Ended
|Net cash provided by operating activities||$||10,622||$||12,234|
|Net cash used in investing activities||(15,726||)||(11,446||)|
|Net cash provided by financing activities||10,103||1,735|
|Effect of exchange rate changes on cash||(1,184||)||(4,104||)|
|Net increase (decrease) in cash, cash equivalents, and restricted cash||$||3,815||$||(1,581||)|
Summary Consolidated Balance Sheets
(in thousands of
|Cash and cash equivalents||$||13,707||$||9,892|
|Accounts receivable, net|
|Oil and natural gas sales||22,339||12,912|
|Joint interest and other||1,113||982|
|Prepaid and other current assets||11,431||8,696|
|Note receivable - related party||–||5,828|
|Total current assets||54,400||44,355|
|Property and equipment:|
|Oil and natural gas properties (successful efforts method)|
|Equipment and other property||12,918||14,408|
|Less accumulated depreciation, depletion and amortization||(103,917||)||(105,850||)|
|Property and equipment, net||81,879||87,259|
|Other long-term assets:|
|Note receivable - related party||4,451||–|
|Total other assets||7,908||986|
|LIABILITIES, SERIES A PREFERRED SHARES AND SHAREHOLDERS' EQUITY|
|Accounts payable - related party||3,007||2,922|
|Total current liabilities||46,743||41,891|
|Asset retirement obligations||4,506||4,667|
|Deferred income taxes||21,845||20,314|
|Total long-term liabilities||47,446||32,240|
|Commitments and contingencies|
|Series A preferred shares,
shares issued and outstanding with a liquidation preference of
|Series A preferred shares-related party,
authorized; 495,000 shares issued and outstanding with a liquidation preference
shares and 52,413,588 shares issued and outstanding as of
|Accumulated other comprehensive loss||(146,663||)||(142,021||)|
|Total shareholders' equity||3,948||12,419|
|Total liabilities, Series A preferred shares and shareholders' equity||$||144,187||$||132,600|
Reconciliation of Net Loss to Adjusted EBITDAX (Unaudited)
(in thousands of
|For the Three Months Ended||For the Six Months Ended|
|Interest and other, net||2,532||2,304||1,714||4,836||4,242|
|Income tax expense||3,366||3,423||1,114||6,789||2,401|
|Exploration, abandonment, and impairment||666||5,113||191||5,779||231|
|Seismic and other exploration expense||108||77||59||185||218|
|Foreign exchange loss||115||1,273||1,938||1,388||3,996|
|Share-based compensation expense||77||102||117||179||218|
|Loss on commodity derivative contracts||323||110||3,141||433||3,866|
|Cash settlements on commodity derivative contracts||-||-||(1,860||)||-||(3,199||)|
|Accretion of asset retirement obligation||49||52||43||101||89|
|Depreciation, depletion, and amortization||3,442||3,716||3,276||7,158||7,735|
Adjusted EBITDAX is a non-GAAP financial measure that represents net loss plus interest and other income, net, income tax expense, exploration, abandonment, and impairment, seismic and other exploration expense, foreign exchange loss, share-based compensation expense, loss on commodity derivative contracts, cash settlements on commodity derivative contracts, accretion of asset retirement obligation, and depreciation, depletion, and amortization.
The Company believes Adjusted EBITDAX assists management and investors in comparing the Company’s performance on a consistent basis without regard to depreciation, depletion, and amortization, impairment of oil and natural gas properties, exploration expenses, and foreign exchange gains and losses among other items, which can vary significantly from period to period. In addition, management uses Adjusted EBITDAX as a financial measure to evaluate the Company’s operating performance.
Adjusted EBITDAX is not a measure of financial performance under GAAP. Accordingly, it should not be considered as a substitute for net income prepared in accordance with GAAP. Net income may vary materially from Adjusted EBITDAX. Investors should carefully consider the specific items included in the computation of Adjusted EBITDAX.
The Company is an international oil and natural gas company engaged in the acquisition, exploration, development, and production of oil and natural gas. The Company holds interests in developed and undeveloped properties in
(NO STOCK EXCHANGE, SECURITIES COMMISSION, OR OTHER REGULATORY AUTHORITY HAS APPROVED OR DISAPPROVED THE INFORMATION CONTAINED HEREIN.)
This news release contains statements concerning the Company’s drilling program, the evaluation of the Company’s prospects in southeastern
Although the Company believes that the expectations reflected in such forward-looking statements or information are reasonable, undue reliance should not be placed on forward-looking statements because the Company can give no assurance that such expectations will prove to be correct. Forward-looking statements or information are based on current expectations, estimates, and projections that involve a number of risks and uncertainties which could cause actual results to differ materially from those anticipated by the Company and described in the forward-looking statements or information. These risks and uncertainties include, but are not limited to, access to sufficient capital; market prices for natural gas, natural gas liquids, and oil products; estimates of reserves and economic assumptions; the ability to produce and transport natural gas, natural gas liquids, and oil products; the results of exploration and development drilling and related activities; economic conditions in the countries and provinces in which the Company carries on business, especially economic slowdowns; actions by governmental authorities; 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 actions by insurgent groups or other conflict; outcomes of litigation; the negotiation and closing of material contracts; and other risks described in the Company’s filings with the
The forward-looking statements or information contained in this news release are made as of the date hereof and the Company undertakes no obligation to update publicly or revise any forward-looking statements or information, whether as a result of new information, future events, or otherwise, unless so required by applicable securities laws.
Note on BOE
Barrels of oil equivalent, or BOE, are derived by the Company by converting natural gas to oil in the ratio of six thousand cubic feet of natural gas (“MCF”) to one stock tank barrel, or 42 U.S. gallons liquid volume (“BBL”), of oil. A BOE conversion ratio of six MCF to one BBL is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. BOE may be misleading, particularly if used in isolation.
Vice President, General Counsel, and Corporate Secretary
Source: TransAtlantic Petroleum Ltd.