VANCOUVER, Aug. 8, 2018 /CNW/ - ShaMaran Petroleum Corp. (“ShaMaran” or the “Company”) (TSX VENTURE: SNM) (OMX: SNM) is pleased to announce its financial and operating results for the six months ended June 30, 2018. Unless otherwise stated all currency amounts indicated as “$” in this news release are expressed in thousands of United States dollars. View in PDF Format.

HIGHLIGHTS

• ShaMaran entered agreement with Marathon Oil KDV BV to acquire their 15% interest in Atrush.
   
• Company issued $240 million in new bonds on July 5 and retired all existing bonds on August 1.
   
• Revenues of $41.8 million with strong operational cash flows in first six months.
   
• Average Atrush production of 19,700 bopd in first half of 2018 with $6.83/barrel average lifting cost.
   
• Current Atrush production approximately 28,000 bopd.
   
• CK-7 completed in Q2 with low drawdown flow test of 7,040 bopd. Brought on line late July.
   
• CK-10 drilled and completed in Q2 with low drawdown flow test of 4,400 bopd. Brought on line late July.
   
• CK-9 water disposal well spudded in July.
   
• 25% increase in 2P reserves announced in February.

 

Chris Bruijnzeels, President and CEO of ShaMaran, commented “We’ve had a lot to cheer about so far this year: the agreement to acquire another 15% in Atrush is highly accretive for ShaMaran and sets the table for significant additional cash flows, the refinancing of our bonds has left the Company with a solid liquidity position, and the recent addition of CK-7 and CK-10 are pushing Atrush production up towards the facility’s nameplate capacity.  And, looking forward to the rest of 2018, I’m excited by our plans to seek out ways to optimise the Atrush production facility and unlock further capacity and to look to better define what kind of long term production potential we have in the eastern side of the block with our planned heavy oil extended well test on AT-3.

Operations

• Current Atrush production at approximately 28,000 barrels of oil per day with production from five wells: AT-2, CK-5, CK-7, CK-8 and CK-10. It is planned to further increase production gradually.
   
• Atrush oil production in three and six months ended June 30, 2018 was 15,800 bopd and 19,700 bopd which compares to 23,600 reported in the first quarter of 2018. The production was impacted by the need to reduce well flow rates to manage higher than expected volumes of salt produced from some wells. Fresh water is now being injected to remove salt during processing of the crude for sales. Average lifting cost per barrel in the second quarter was $7.97 and $6.83 in the first six months.
   
• CK-7 completed in Q2 2018 and tested 27.5 API oil at 7,040 bopd at only 14 psi drawdown. CK-7 was tied into the production facility in July 2018 and came on line on July 23, 2018.
   
• CK-10 drilled on time and within budget during May and June 2018, and flow tested approximately 4,400 bopd at a low drawdown. CK-10 was tied into the production facility in July 2018 and came on line on July 25, 2018.
   
• The CK-9 water disposal well was spudded on July 20, 2018 with planned well depth of 3,000 metres 70-day drill time. The main objective is to target deep horizons below the oil reservoir to allow for disposal of produced water that is expected as production continues. The well will also be used to dispose of water injected in to the process as part of the salt management strategy.

 

Financial and Corporate

• ShaMaran entered into an agreement on June 4, 2018 to acquire a further 15% interest in Atrush from Marathon Oil KDV BV (“Marathon”) for $60 million before closing adjustments (“the Marathon Acquisition”). The Company current holds a 20.1% interest in Atrush. At the date of this news release certain closing conditions remained outstanding.
   
• ShaMaran issued new $240 million senior unsecured bonds on July 5, 2018 with 5-year term and 12% semi-annual coupon interest. On August 1, 2018 the existing bonds were retired. They were due to mature in November 2018.
   
• Principal cash inflows in the six months ended June 30, 2018:
   
  • $40.4 million for entitlement share of Atrush PSC profit oil and cost oil for October 2017 through March 2018 oil deliveries. A further $4.4 million was received in July relating to April 2018 oil sales.
     
  • $1.2 million of Atrush Exploration Costs receivable[1] on October 2017 through March 2018 oil sales. A further $0.1 million was received in July relating to April 2018 oil sales.
     
  • $7.8 million in payments of principal plus interest on the Atrush Development Cost Loan and the Atrush Feeder Pipeline Cost loans for invoices from January to June 2018. A further $1.3 million was received in July relating to the July 2018 KRG Loan invoice.
     
• A new sales agreement was concluded in February 2018 between Atrush co-venturers and the KRG for the sale of Atrush oil. The KRG buys oil exported from the Atrush field by pipeline at the Atrush block boundary based upon the Dated Brent oil price minus $15.73 for quality discount and all local and international transportation costs.
   
• On February 15, 2018 the Company reported estimated reserves and contingent resources for the Atrush field as at December 31, 2017. Total Field Proven plus Probable (“2P”) Reserves on a property gross basis for Atrush increased from 85.1 MMbbl reported as at December 31, 2016 to 102.7 MMbbl which, when 2017 Atrush production of 3.4 MMbbl is included, represents an increase of 25 percent. Total Field Unrisked Best Estimate Contingent Oil Resources (“2C”)[2] on a property gross basis for Atrush was approximately the same as the 2016 estimate at 296 MMbbl. Total discovered oil in place in the Atrush Block is a low estimate of 1.5 billion barrels, a best estimate of 2.1 billion barrels and a high estimate of 2.9 billion barrels.

 

 

OUTLOOK

Operations

• Production guidance for the second half of 2018 is 25,000-30,000 bopd. Guidance for 2018 lifting costs remains unchanged at $6.80/bbl in light of higher expected production for the rest of 2018.
   
• Capital expenditure guidance has been lowered from previous estimate of $19.6 million to $17.0 million (20.1% working interest in Atrush), principally due to lower than planned drilling and testing costs on CK-7 and CK-10. Remaining planned capital expenditure includes:
   
  • identify and install additional heat sources ahead of the next winter months;
     
  • continue with program to identify debottleneck opportunities to further increase production capacity beyond 30,000 bopd;
     
  • drilling and completion of Chiya Khere (“CK-9”), a dedicated water disposal well; and
     
  • conducting extended testing of the AT-3 well which is located on the eastern side of the Atrush Block and which is outside the 2P reserve area of Atrush. This would involve the installation of temporary production facilities near the Chamanke–C well pad and the delivery by truck of oil to the main Phase 1 Production Facilities.
     
• Following the results of the CK-7 and CK-10 wells, the extended well testing in AT-3 and sustained production from the Phase 1 Production Facilities the Company expects to further assess the significant undeveloped Atrush resource base with the potential to grow organically to approximately 100,000 bopd production.

 

Financing and corporate

• A cash payment to Marathon is due upon close of the Marathon Acquisition for $60 million less the $2 million deposit and less all other final closing adjustments which will include net Atrush cash flows received by Marathon after January 1, 2018, the effective date of the acquisition.
   
• Two cash payments of $14.4 million each to be made by the Company into the Debt Service Retention Account pledged to the Company’s bondholders. The payments are due on December 31, 2018 and June 30, 2019.
   
• The first semi-annual coupon interest payment of $14.4 million under the Company’s $240 million bonds is due January 5, 2019.

 

FINANCIAL RESULTS FOR THE THREE AND SIX MONTHS ENDED JUNE 30, 2018

Oil production commenced on July 3, 2017 from the Atrush Block located in the Kurdistan Region of Iraq. Atrush production operations and work on the Atrush development program continued throughout the first six months of 2018. 

Financial Results

The net income was primarily driven by the gross margin on Atrush oil sales and interest income on Atrush cost loans to the KRG and was reduced by general and administrative expenses and finance cost, the substantial portion of which were expensed borrowing costs on the Company’s Senior Bonds and Super Senior Bonds.
 

 

 

Total assets increased in the first half of 2018 by $14.0 million due to a decrease in the accumulated deficit by $14.6 million, related to the income generated in the period, and increases in borrowings, accrued interest and other non-current liabilities by $1.6 million, net of a decrease in accounts payable and accrued expenses by $2.2 million.

Property, plant & equipment assets decreased during the 6 months ended June 30, 2018 by $3.4 million which was due to depletion and depreciation costs of $14.2 million net of additions of $6.5 million in Atrush development costs, $3.8 million in capitalised borrowing costs and a one-time cost reclass to PP&E from E&E of $0.5 million.  The decrease in intangible assets by $195 thousand during the half of 2018 resulted from Atrush exploration and evaluation costs of $132 thousand and $175 thousand in capitalised borrowing costs net of $498 thousand relating to the reclass to PP&E from E&E and $4 thousand in amortisation and revaluation of foreign currency item. Loans and receivables decreased by $6.5 million due to collecting $7.1 million of Atrush Development Cost and Feeder Pipeline Cost loans and $1.2 million of Atrush Exploration Cost Receivables, net of accruing an additional $1.4 million of accounts receivables on Atrush oil sales and funding $0.4 million of Feeder Pipeline costs.

 

The increase by $22.0 million in the cash position of the Company in the first six months of 2018 was due to cash inflows of $35.1 million from operating activities after G&A and other cash expenses and $9.1 million of principal and interest payments on KRG loans and the Exploration Cost Receivables which were offset by cash outflows of $5.3 million on Atrush development activities, $0.4 million of loans provided to the KRG, $5.8 million of negative cash adjustments on accounts receivables, payables and other working capital items and $10.7 million on bond coupon interest         .

OTHER

This information in this release is subject to the disclosure requirements of ShaMaran Petroleum Corp. under the EU Market Abuse Regulation and/or the Swedish Securities Market Act. This information was publicly communicated on August 8, 2018 at 5:30 p.m. Toronto Time.

ABOUT SHAMARAN

ShaMaran Petroleum Corp. is a Kurdistan focused oil development and exploration company with a 20.1% direct interest in the Atrush oil discovery. As announced in ShaMaran’s June 4, 2018 news release, the Company has signed an agreement with Marathon Oil KDV B.V. to acquire its 15% interest in the Atrush Block. The Atrush Block is currently undergoing an appraisal and development campaign.

ShaMaran is a Canadian oil and gas company listed on the TSX Venture Exchange and the NASDAQ Stockholm First North Exchange (Sweden) under the symbol “SNM”. Neither the TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this release. Pareto Securities AB is the Company’s Certified Advisor on NASDAQ Stockholm First North.

The Company’s condensed interim consolidated financial statements, notes to the financial statements and management’s discussion and analysis have been filed on SEDAR (www.sedar.com) and are also available on the Company’s website (www.shamaranpetroleum.com).

FORWARD LOOKING STATEMENTS

This news  release contains statements and information about expected or anticipated future events and financial results that are forward-looking in nature and, as a result, are subject to certain risks and uncertainties, such as legal and political risk, civil unrest, general economic, market and business conditions, the regulatory process and actions, technical issues, new legislation, competitive and general economic factors and conditions, the uncertainties resulting from potential delays or changes in plans, the occurrence of unexpected events and management’s capacity to execute and implement its future plans. Any statements that are contained in this news release that are not statements of historical fact may be deemed to be forward-looking information. Forward-looking information typically contains statements with words such as “may”, “will”, “should”, “expect”, “intend”, “plan”, “anticipate”, “believe”, “estimate”, “projects”, “potential”, “scheduled”, “forecast”, “outlook”, “budget” or the negative of those terms or similar words suggesting future outcomes. The Company cautions readers regarding the reliance placed by them on forward‐looking information as by its nature, it is based on current expectations regarding future events that involve a number of assumptions, inherent risks and uncertainties, which could cause actual results to differ materially from those anticipated by the Company. 

Actual results may differ materially from those projected by management. Further, any forward-looking information is made only as of a certain date and the Company undertakes no obligation to update any forward-looking information or statements to reflect events or circumstances after the date on which such statement is made or reflect the occurrence of unanticipated events, except as may be required by applicable securities laws. New factors emerge from time to time, and it is not possible for management of the Company to predict all factors and to assess in advance the impact of each such factor on the Company’s business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking information.

Reserves and resources: ShaMaran Petroleum Corp.’s reserve and contingent resource estimates are as at December 31, 2017, and have been prepared and audited in accordance with National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities (“NI 51-101”) and the Canadian Oil and Gas Evaluation Handbook (“COGE Handbook”). Unless otherwise stated, all reserves estimates contained herein are the aggregate of “proved reserves” and “probable reserves”, together also known as “2P reserves”. Possible reserves are those additional reserves that are less certain to be recovered than probable reserves. There is a 10% probability that the quantities actually recovered will equal or exceed the sum of proved plus probable plus possible reserves.

Contingent resources: Contingent resources are those quantities of petroleum estimated, as of a given date, to be potentially recoverable from known accumulations using established technology or technology under development, but are not currently considered to be commercially recoverable due to one or more contingencies. Contingencies may include factors such as economic, legal, environmental, political and regulatory matters or a lack of markets. There is no certainty that it will be commercially viable for the Company to produce any portion of the contingent resources.

BOEs: BOEs may be misleading, particularly if used in isolation. A BOE conversion ratio of 6 Mcf per 1 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.

SOURCE ShaMaran Petroleum Corp.