ShaMaran Q3 2017 Financial and Operating Results

ShaMaran Q3 2017 Financial and Operating Results

November 16, 2017

VANCOUVER, BRITISH COLUMBIA–(Marketwired - Nov. 16, 2017) -ShaMaran Petroleum Corp. (“ShaMaran” or the “Company”) (TSX VENTURE:SNM)(OMX:SNM) is pleased to announce its financial and operating results for the three and nine months ended September 30, 2017. Unless otherwise stated all currency amounts indicated as “$” in this news release are expressed in thousands of United States dollars.



  • Oil production on the Atrush Block commenced in July 2017. Atrush is currently producing at approximately 26 thousand barrels of oil per day (“bopd”). In order to address certain production constraints the facilities were shut down in the beginning of October. These constraints have now successfully been resolved.
  • One of the four production wells, Atrush 4, (“AT-4”) is currently shut in. The well was back-producing drilling fluid lost during drilling operations. In order to not upset the production system it was decided to clean up the well via temporary facilities upon the receipt of a flare permit from the Kurdistan Regional Government (“KRG”). This operation is now planned for Q4 2017.
  • In October and November 2017 the Company received payments totalling $2.5 million representing its entitlement share of the $9.7 million in total payments received by the Atrush Non-Government Contractors from the KRG for July and August oil sales from Atrush and reimbursement instalments of the Atrush Exploration Costs receivable. 703 thousand barrels of oil were exported from Atrush for the months of July and August with an average netback price1 of $35.3 per barrel of oil. Total oil produced and exported from Atrush over the third quarter was 1.3 million barrels resulting in an average of 14.6 thousand barrels per day. The average netback price over the quarter was $36.86 per barrel and the average lifting cost was $8.54 per barrel.
  • The Chiya Khere-7 (“CK-7”), which was spudded on September 17, 2017 reached a final depth of 1,861 metres in early November 2017. The reservoir section was encountered approximately 114 metres shallower than prognosis. The well was drilled on time and under budget. Testing and completion of the well will be performed in 2018 to coincide with installation of flow lines between the Production Facility and the Chamanke E location were the well is located. The main objectives of the well are to appraise the commercial potential of the Mus formation, to help reduce the uncertainty in the location of the medium to heavy oil transition zone and to serve as a further producing well.
  • In September 2017 an agreement was concluded between the Atrush Non-Government Contractors and the KRG for the sale of Atrush oil whereby the KRG will buy oil exported from the Atrush field by pipeline at the Atrush block boundary based upon the Dated Brent oil price minus approximately $16 for quality discount and all local and international transportation costs. This discount is based on the same principles as other oil sales agreements in the Kurdistan Region of Iraq.
  • The Final Completion Certificate for the Atrush Feeder Pipeline (“FCC”) was issued on October 31, 2017 which completes the obligation of the Non-Government Contractors to fund the KRG’s share of development costs and triggers the commencement of repayment of both the Atrush Feeder Pipeline Cost Loan and the Atrush Development Cost Loan. The first loan repayment instalments are due later in November 2017.
  • Following the independence referendum held in Kurdistan on September 25, 2017, operations in the Atrush field in Kurdistan are continuing in a normal, safe and secure manner. Exports from Atrush are continuing via the Kurdistan Export Pipeline system and drilling operations on the CK-7 well are progressing as planned. Nevertheless, events since the referendum suggest an increase in the potential for political instability within the region.

1 This includes a discount to Dated Brent for oil quality and all local and international transportation costs.


  • On January 30, 2017 the Company completed the issue of 360 million common shares of ShaMaran on a private placement basis (the “Private Placement”) at a price per share of CAD 0.10 (equal to SEK 0.67) which resulted in gross proceeds to the Company of $27.3 million ($26.4 million net of transaction related costs). Zebra Holdings and Investments SARL, Lorito Holdings SARL and Lundin Petroleum BV, the Company’s major shareholders, subscribed for 43,463,618 shares, 16,984,621 shares and 17,800,000 shares, respectively, in the Private Placement.
  • In February 2017 the Company reported estimated reserves and contingent resources for the Atrush block as of December 31, 2016. Reserves and resource estimates have remained unchanged from those reported for the prior year. 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 2.8 billion barrels, with Total Field Proven plus Probable (“2P”) Reserves on a property gross basis estimated at 85.1 MMbbl and Total Field Unrisked Best Estimate Contingent Resources (“2C”) on a property gross basis estimated at 304 million barrels oil equivalent (MMboe). 2 3

2 “MMbbl” means million barrels and “MMboe” means million barrels of oil equivalents. Boe may be misleading, particularly if used in isolation. A boe conversion ratio of 6 million cubic feet (“Mcf”) per one barrel is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead.

3 This estimate of remaining recoverable resources (unrisked) includes contingent resources that have not been adjusted for risk based on the chance of development. It is not an estimate of volumes that may be recovered.



In the fourth quarter of 2017 it is planned to produce the AT-4 well until clean via temporary facilities and bring Atrush production up to the facilities’ design capacity of 30,000 bopd.
Plans for Atrush for 2018 include:
 continue with program to identify bottlenecks in order to maximise output from the Production Facility;
 testing and completion of the CK-7 well;
 install the CK-7 flow line and bring CK-7 into production;
 drilling, testing and completion of Chiya Khere (“CK-10”), a sixth development well;
 drilling and completion of Chiya Khere (“CK-9”), a dedicated water disposal well; and
 conducting extended testing of the CK-6 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 CK-6 and sustained production from the Phase 1 Production Facilities the Company expects to be in a position to further assess the significant undeveloped Atrush resource base.
The political situation in the Kurdistan region will be monitored continuously and the market will be appraised of any material impact on operational activity.


During the reporting period production commenced from the Atrush Block petroleum property located in the Kurdistan Region of Iraq and work continued on the Atrush development program.

Financial Results

The Company reports a net loss of $9.5 million for the nine months ended September 30, 2017 which was primarily driven by a negative margin on Atrush oil sales, 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. These expenses have been slightly offset by interest income on Atrush cost loans to the KRG and interest on cash held in short term deposits.

Condensed Interim Statement of Comprehensive Income 
(Unaudited, expressed in thousands of United States Dollars) 
 Three months 
ended September 30,
  Nine months 
ended September 30,
 2017 2016  2017 2016 
Revenues3,782 -  3,782 - 
Cost of goods sold(4,583)-  (4,583)- 
Gross loss(801)-  (801)- 
Service fee income- 90  - 120 
Share based payments expense- (58) (11)(192)
Depreciation and amortisation expense(8)(12) (26)(34)
General and administrative expense(1,637)(695) (3,545)(3,006)
Loss from operating activities(2,446)(675) (4,383)(3,112)
Finance income525 16  1,288 39 
Finance cost(3,436)(1,393) (6,393)(4,228)
Net finance cost(2,911)(1,377) (5,105)(4,189)
Loss before income tax expense(5,357)(2,052) (9,488)(7,301)
Income tax expense(36)(14) (71)(55)
Loss for the period(5,393)(2,066) (9,559)(7,356)
Other comprehensive income         
Items that may be reclassified to profit or loss:
Currency translation differences
1 (11) 35 53 
Actuarial loss on defined pension plan- -  - (505)
Total other comprehensive income1 (11) 35 (452)
Total comprehensive loss for the period(5,392)(2,077) (9,524)(7,808)
Condensed Interim Consolidated Balance Sheet 
(Unaudited, expressed in thousands of United States Dollars) 
 At September 30, 2017 At December 31, 2016 
Non-current assets    
Property, plant and equipment189,365 174,658 
Intangible assets89,280 89,007 
Loans and receivables48,580 46,114 
 327,225 309,779 
Current assets    
Loans and receivables19,428 7,252 
Cash and cash equivalents6,982 4,416 
Other current assets279 224 
 26,689 11,892 
Total assets353,914 321,671 
Liabilities and equity    
Current liabilities    
Accounts payable and accrued expenses6,054 6,434 
Accrued interest expense on bonds7,715 2,503 
 13,769 8,937 
Non-current liabilities    
Borrowings175,345 165,129 
Provisions9,227 8,869 
Pension liability1,661 1,670 
 186,233 175,668 
Total liabilities200,002 184,605 
Share capital637,538 611,179 
Share based payments reserve6,495 6,484 
Cumulative translation adjustment(26)(61)
Accumulated deficit(490,095)(480,536)
Total equity153,912 137,066 
Total liabilities and equity353,914 321,671 

Total assets increased during the first nine months of 2017 by $32.2 million as a result of increases in share capital and equity reserves by $26.4 million, borrowings by $10.2 million, current liabilities by $4.8 million and other non-current liabilities by $0.4 million which were offset by an increase in the accumulated deficit by $9.6 million, principally due to the net loss recorded in the period.

Property, plant & equipment assets increased during the three quarters ended September 30, 2017 by $14.7 million which was due to additions of $8.0 million in Atrush development costs and $9.0 million in capitalised borrowing net of $2.3 million in depletion costs. The increase in intangible assets by $0.3 million during the first nine months of 2017 resulted from additions of $0.2 million and from 0.1 million in capitalised borrowing costs. Loans and receivables increased by $14.6 million from funding $6.2 million of Feeder Pipeline costs, $3.8 million of accounts receivables on Atrush oil sales, funding $3.4 million of the KRG’s share of development costs and $1.2 million of accrued interest on the outstanding loan balances.

Condensed Interim Consolidated Cash Flow Statement 
(Unaudited, expressed in thousands of United States Dollars) 
 Three months 
ended September 30,
 Nine months 
ended September 30,
 2017 2016 2017 2016 
Operating activities        
Loss for the period(5,393)(2,066)(9,559)(7,356)
Adjustments for:        
 Interest expense on borrowings - net3,431 1,375 6,375 4,103 
 Depreciation, depletion and amortisation expense2,290 12 2,308 34 
 Unwinding discount on decommissioning provision7 19 - 62 
 Share based payments expense- 58 11 192 
 Pension expense- - 11 14 
 Foreign exchange (gain) / loss(7)(10)19 64 
 Interest income(518)(6)(1,288)(39)
 Changes in current tax liabilities- (8)- (31)
 Changes in other current assets(40)(41)(55)(84)
 Changes in accounts payable and accrued expenses(81)(4,317)(380)(4,970)
 Changes in accounts receivables on Atrush oil sales(3,782)- (3,782)- 
Net cash outflows to operating activities(4,093)(4,984)(6,340)(8,011)
Investing activities        
Interest received on cash deposits29 6 94 39 
Purchases of intangible assets(149)(58)(185)(56)
Purchase of property, plant and equipment(1,435)(8,641)(7,746)(25,186)
Loans and receivables - advances to joint venture partner(2,133)- (9,610)- 
Net cash outflows to investing activities(3,688)(8,693)(17,447)(25,203)
Financing activities        
Proceeds from shares issued- - 27,281 - 
Share issue related transaction costs- - (922)- 
Proceeds from shares issued- - - 17,000 
Bond transaction costs- - - (780)
Net cash inflows from financing activities- - 26,359 16,220 
Effect of exchange rate changes on cash and cash equivalents4 (3)(6)(14)
Change in cash and cash equivalents(7,777)(13,680)2,566 (17,008)
Cash and cash equivalents, beginning of the period14,759 28,593 4,416 31,921 
Cash and cash equivalents, end of the period6,982 14,913 6,982 14,913 

The increase by $2.6 million in the cash position of the Company during the first nine months of 2017 was due to cash inflows of $26.4 million in net proceeds from the sale of the Company’s shares in a private placement completed in January 2017 which were offset by spending of $7.9 million on Atrush development activities, $9.6 million of financing provided to a joint venture partner, $5.9 million of cash out on G&A and other cash expenses and $0.4 million of cash out on payables and other working capital items.


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 November 16, 2017 at 23:30 Central European Time.


ShaMaran Petroleum Corp. is a Kurdistan focused oil development and exploration company with a 20.1% direct interest in the Atrush oil discovery. 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 First North Exchange (Stockholm) 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 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 ( and are also available on the Company’s website (


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 of these 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, 2016, 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.

Chris Bruijnzeels
President and CEO
ShaMaran Petroleum Corp.
+41 22 560 8605

Sophia Shane
Corporate Development
ShaMaran Petroleum Corp.
+1 604 689 7842

Robert Eriksson
Investor Relations, Sweden
ShaMaran Petroleum Corp.
+46 701 112615
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