WesternZagros Announces Third Quarter 2016 Operational and Financial Results

CALGARY, ALBERTA--(Marketwired - Nov. 17, 2016) -

NOT FOR DISTRIBUTION TO U.S. NEWSWIRE SERVICES OR DISSEMINATION IN THE UNITED STATES

WesternZagros Resources Ltd. (TSX VENTURE:WZR) ("WesternZagros" or "the Company") announced today its operating and financial results for the third quarter ended September 30, 2016. A summary of the activities, the financial statements, and the accompanying Management Discussion and Analysis ("MD&A") are available at www.westernzagros.com and on SEDAR at www.sedar.com. All amounts set out in this news release are in US dollars unless otherwise stated.

Commenting on the third quarter results and subsequent events, WesternZagros's Chief Executive Officer Simon Hatfield said:

"The Company made steady progress in the quarter against several objectives, including fortifying our balance sheet and maintaining our lowered capital requirements. At Sarqala, our revenue for the year to date is $10 million and we're pleased that we have received payment from the KRG to the end of September. The Sarqala-1 well has now produced just under four million barrels of light oil with no indications of formation water and no hydrogen sulphide. In the third quarter, we also received $5.5 million of insurance proceeds and further deferred the draw down dates of our debt facility. The revised dates now better align with the anticipated spud of the Sarqala-2 well in the third quarter of next year.

Discussions with our co-venturers on advancing development of the Kurdamir and Garmian blocks continue to progress, with our aim being to advance investment in the region in line with sustained regular payments for production. We are excited to demonstrate the high quality, long-life and strong economics of our projects on both blocks but intend to take full advantage of our increased financial flexibility to hold the pace of spending in line with market conditions."

Financial and Operating Highlights

• Financial - The Company ended the third quarter with $32.7 million in cash and cash equivalents and an undrawn $200 million credit facility provided by Crest Energy International LLC ("Crest"). In the quarter, the Company received $5.5 million from an insurance claim related to the drilling program for the Hasira-1 well. The Company entered into a third letter agreement with Crest on October 18, 2016 to further extend the timing to draw on the credit facility to better meet the Company's capital expenditure profile and reduce near term financing costs.
  
  
• Production - Third quarter gross oil sales averaged 5,329 barrels of light oil per day ("bbl/d"), of which WesternZagros's net oil sales were 1,437 bbl/d. Total gross oil sales delivered in the quarter were approximately 490,000 barrels ("bbl") from the Sarqala field with 132,000 bbl net to the Company. The Sarqala-1 well has now produced just under four million barrels of light oil with no indications of formation water and no hydrogen sulphide.
  
  
• Revenue - Revenue recognized by WesternZagros was $4.6 million for approximately 132,000 bbl (net) oil sales delivered during the third quarter with an average realized price of $34.98/bbl. Subsequent to September 30, 2016, the Company collected $2.4 million of oil sales proceeds related to the second quarter and $4.6 million of oil sales proceeds related to the third quarter. At Sarqala, our revenue for the year to date is $10 million, representing full payment in accordance with production sharing contract entitlements.
  
  
• Cost Reduction Initiatives - WesternZagros continued cost control emphasis in the third quarter and will maintain a conservative approach to capital spending for the remainder of 2016. Both operating and overhead costs will be scrutinized on an itemized basis targeting further cost reductions and operating efficiencies in 2017.
  
  
• Corporate - WesternZagros continues to review strategic initiatives to improve financial flexibility including but not limited to potentially accessing the debt and/or equity markets or seeking additional partnerships, farmouts or other strategic arrangements.
  
  

Operations

WesternZagros's assets comprise two contract areas, the Kurdamir and Garmian blocks, with significant oil and natural gas discoveries. The timeframe for advancing investment plans on the Garmian and Kurdamir blocks is subject to, among other factors, the stability of payments for existing production.

Garmian Block

• The Garmian FDP, approved in May 2016, is focused on the development of the Jeribe/Upper Dhiban reservoir which is estimated to contain 13 MMbbl of 2P oil Reserves and 66 MMbbl of unrisked P50 Prospective oil Resources (both Gross Block). The first phase of development includes the continuation of production from the Sarqala-1 well, and the drilling of two additional development wells to increase production and to convert prospective resources into reserves.
• The Sarqala-2 well is anticipated to spud in the third quarter of 2017 and is planned to target a fractured portion of the reservoir identified on the 3D seismic. The Sarqala-3 well is planned to follow with similar objectives. The potential for further development of the Jeribe/Upper Dhiban reservoir will be assessed following the results from this first phase. Third quarter gross oil sales for the Sarqala field averaged 5,329 bbl/d of light oil, of which WesternZagros's net oil sales were 1,437 bbl/d. Total gross oil sales delivered in the quarter were approximately 490,000 bbl for the Sarqala field, 132,000 bbl net to the Company.

Kurdamir Block

• WesternZagros and its co-venturer, Repsol, submitted a revised Kurdamir FDP to the KRG in May 2016 to develop the significant oil and gas resources discovered on the Kurdamir Block. The parties have received feedback from the KRG on the FDP and are working to finalize a revised plan with submission planned for the fourth quarter.
• The Kurdamir FDP is a phased development that will be executed over a period of several years. Phase 1 is focused on the development of the Oligocene oil and gas discovery and includes a CPF shared equally between the Kurdamir Block and Repsol's adjacent Topkhana block. The facility will have a capacity of 150 mmcf/d of gas per day with liquids handling for condensate and oil. Repsol is the operator of both the Topkhana and Kurdamir blocks.
• The co-venturers and the KRG continue to negotiate a gas sales agreement to provide Phase 1 gas from the Kurdamir and Topkhana blocks to the domestic market. Future phases are anticipated to provide gas to the export market. In addition, the KRG is responsible for the construction of a gas sales pipeline from the Kurdamir/Topkhana block boundary to the nearest market tie in point at Chemchemal. A final investment decision to advance the project is anticipated upon completion of the gas sales negotiations, the pipeline engineering, procurement and construction award and approval of the Kurdamir FDP.

Corporate Management

• During the third quarter of 2016, the Company remained focused on executing its plans to maintain production and minimize costs. Sustainability during the prolonged volatile market environment remains a key objective.
• WesternZagros continues to review strategic initiatives to improve financial flexibility including but not limited to potentially accessing the debt and/or equity markets or seeking additional partnerships, farmouts or other strategic arrangements.

Financial

• As at September 30, 2016, WesternZagros had $32.7 million in cash and cash equivalents and an undrawn $200 million credit facility provided by Crest Energy International LLC ("Crest"), which is available in two tranches of up to $50 million and up to $150 million, subject to certain conditions precedent to drawdown.
• On October 18, 2016, the Company and Crest entered into a letter agreement to further extend the deadline date by which the Company must deliver to Crest the first drawdown notice for each of the two tranches to better align with the Company's anticipated capital needs. The drawdown deadline for the $50M tranche has been extended from November 1, 2016 to March 1, 2017. In addition, the maturity date for this tranche has been extended from November 1, 2018 to March 1, 2019. The drawdown deadline for the $150M tranche has been extended from April 1, 2017 to August 1, 2017, with a corresponding extension of the maturity date for this tranche from April 1, 2019 to August 1, 2019.
• The Company received $5.5 million from an insurance claim related to the drilling program for the Hasira-1 well, where testing of the well had to be prematurely terminated in early 2015 due to a considerable influx of reservoir formation debris plugging the tubing. The Hasira-1 well was safely suspended in the third quarter of 2015 and future options to utilize the well bore continue to be evaluated. These proceeds were credited against E&E expenditures.
• Revenue recognized was $4.6 million for approximately 132,000 bbl (net) oil sales delivered during the third quarter with an average realized price of $34.98/bbl. Subsequent to September 30, 2016, the Company realized oil sales proceeds of $2.4 million for the second quarter and $4.6 million for the third quarter, with no remaining outstanding oil sales receivables for the third quarter. At Sarqala, our revenue for the year to date is $10 million, representing full payment in accordance with production sharing contract entitlements.
• The Company capitalized $1.1 million of exploration and evaluation ("E&E") expenditures for the quarter, related mainly to WesternZagros's 60 percent share of Kurdamir Block appraisal costs.
• The Company capitalized its 50 percent share of applicable oil and natural gas assets expenditures to property, plant and equipment related to Garmian Block activities of $3.9 million, which was comprised of Sarqala-2 planning costs, production facilities upgrades, related in-country supervision and office costs.

Outlook

WesternZagros continues to focus on advancing development in accordance with the approved Garmian FDP and securing KRG approval of the phased development plan for the Kurdamir Block in line with market conditions and dependent upon the sustainability of regular payments for production.

For the remainder of 2016, the Company anticipates the average daily productive capacity of Sarqala-1 will be approximately 5,000 bbl/d. Assuming continuous production and an average Brent price of $40 to $50 per barrel, WesternZagros estimates revenues for the remainder of 2016 to be $3.5 to 5.0 million.

In 2017, the Company anticipates the average daily productive capacity of Sarqala-1 will range from 4,500 to 5,000 bbl/d. Assuming continuous production and payments for the year, and an average Brent price of $45 to $50 per barrel, WesternZagros estimates 2017 revenues of $15 to $19 million.

The Company has $32.7 million in cash and cash equivalents as at September 30, 2016 to advance the field development plans with its co-venturers. The Company estimates spending for the remainder of the year of approximately $13 million to operate the Sarqala production operations, advance the respective development of the Kurdamir and Garmian blocks with its co-venturers and cover WesternZagros head office costs. The first Garmian development well is anticipated to spud in the third quarter of 2017.

As previously announced, the Company has further extended the timing for the draw down dates under the Crest Loan Agreement providing the Company with additional flexibility and reducing potential financing costs as it works to finalize its development plans and capital programs. The Company continues its focus on strict cost management. In addition, the Company is reviewing all financing alternatives including but not limited to, the completion of an alternative debt financing or equity financing, or the farm down or sale of some of the assets of the Company to advance the developments. The Company will provide further guidance on the anticipated quantum and timing of capital expenditures for the respective Kurdamir and Garmian projects as the field development plans and related development budgets are finalized and approved.

About WesternZagros Resources Ltd.

WesternZagros is an international natural resources company focused on acquiring properties and exploring for, developing and producing crude oil and natural gas in Iraq. WesternZagros, through its wholly-owned subsidiaries, holds a 40 percent working interest in two Production Sharing Contracts with the Kurdistan Regional Government in the Kurdistan Region of Iraq. WesternZagros's shares trade in Canada on the TSX Venture Exchange under the symbol "WZR".

This news release contains certain forward-looking statements relating to, but not limited to, expected working capital, expected capital and other commitments and the timing thereof, expectations regarding the necessity for further funding and the timing and potential sources thereof, operational information, future development concepts and plans and capacity of facilities and expected production rates, revenues, field netback, and petroleum costs (as defined in each Production PSC). Forward-looking information typically contains statements with words such as "anticipate", "estimate", "expect", "potential", "could", or similar words suggesting future outcomes. The Company cautions readers and prospective investors in the Company's securities to not place undue reliance 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 WesternZagros.

Forward looking information is not based on historical facts but rather on management's current expectations as well as assumptions made by, and information currently available to management, concerning, among other things, development plans and concepts, future capital and other expenditures (including the amount, nature and sources of funding thereof), the ability to identify appropriate financing transactions, the outcomes of future well operations, results of drilling activity and testing, future capital and other expenditures (including the amount, nature and sources of funding thereof), the availability of debt financing or access to alternate financing, the continued ability to sell production in the domestic or export markets and the payments to be received in connection therewith, anticipated operating costs, future economic conditions, future currency and exchange rates, continued political stability, continued security in the Kurdistan Region, timely receipt of any necessary co-venturer, government or regulatory approvals, the successful resolution of any disputes, the Company's continued ability to employ qualified staff and to obtain equipment in a timely and cost efficient manner and the participation of the Company's co-venturers in joint activities. In addition, budgets are based upon WesternZagros's current development plans and anticipated costs, both of which are subject to change based on, among other things, the outcome of negotiations with co-venturers and the government, the actual outcomes of well operations and the installation and commissioning of facilities, unexpected delays, availability of future financing and changes in market conditions. Although the Company believes the expectations and assumptions reflected in such forward-looking information are reasonable, they may prove to be incorrect.

Forward-looking information involves significant known and unknown risks and uncertainties. A number of factors could cause actual results to differ materially from those anticipated by WesternZagros including, but not limited to, risks associated with the oil and gas industry (e.g. operational risks in development and production; inherent uncertainties in interpreting geological data; changes in plans with respect to capital expenditures; interruptions in operations together with any associated insurance proceedings; the uncertainty of estimates and projections in relation to timing, costs and expenses and health, safety and environmental risks), the risk of commodity price and foreign exchange rate fluctuations, risks relating to domestic refining capacity and continuing ability to access the domestic market, risks relating to the ability to access export markets and receive payments in accordance with the PSC terms on a timely basis, the uncertainty associated with any dispute resolution proceedings, the uncertainty associated with negotiating with foreign governments and risk associated with international activity, including the lack of federal petroleum legislation and ongoing political disputes and recent terrorist activities in Iraq in particular.

Readers are cautioned that the foregoing list of important factors is not exhaustive and that these factors and risks are difficult to predict. The forward-looking statements contained in this news release are made as of the date of this news release and, except as required by law, WesternZagros does not undertake any obligation to update publicly or to revise any of the included forward-looking statements, whether as a result of new information, future events or otherwise. The forward-looking statements contained in this news release are expressly qualified by this cautionary statement. See the "Risk Factors" section of the Company's AIF dated March 16, 2016 filed on SEDAR at www.sedar.com for a further description of these risks and uncertainties facing WesternZagros. Additional information relating to WesternZagros is also available on SEDAR at www.sedar.com, including the Company's AIF.

Non-IFRS Measures

Field netback is a non-IFRS measure that represents the Company's working interest share of oil sales, after deducting royalties and operating expenses. Management believes that the field netback is a useful measure to analyze operating performance and provides an indication of the Company's results of business activities prior to other income and expenses. Field netback does not have a standard meaning under IFRS and may not be comparable to similar measures used by other companies. It should not be considered in isolation or as a substitute for measures of performance prepared in accordance with IFRS such as total income (loss) or cash flow from (used in) operating activities. See the "Financial Performance" section of the Company's MD&A dated August 10, 2016 for a reconciliation of field netback.

Reserves and Resources Advisory

In addition, statements relating to reserves and other resources contained herein are deemed to be forward-looking statements, as they involve the implied assessment, based on certain estimates and assumptions that the resources described can be economically produced in the future. Future net revenue values are estimated values only and do not represent fair market value. There is no assurance that the forecast prices and cost assumptions, the initial phases of the development plans as submitted to the KRG and anticipated future phases contemplated in completing the full field development utilized in such estimated values will be attained and variances could be material. The reserve and resource estimates provided herein are estimates only and there is no assurance that the estimated reserves and other resources will be recovered. Actual reserves and other resources may be greater than or less than the estimates provided herein. Terms related to resource classifications referred to herein are based on the definitions and guidelines in the Canadian Oil and Gas Evaluation Handbook which are as follows. The reserves have been evaluated by Sproule International Limited ("Sproule"). Resources other than reserves have been estimated by the Company and audited by Sproule.

"Reserves" are estimated remaining quantities of oil and natural gas and related substances anticipated to be recoverable from known accumulations, as of a given date, based on (a) analysis of drilling, geological, geophysical and engineering data, (b) the use of established technology and (c) specified economic conditions which are generally accepted as being reasonable and shall be disclosed. Reserves are classified as Proved, Probable or Possible according to the degree of certainty associated with the estimates. "Proved Reserves" are those Reserves that can be estimated with a high degree of certainty to be recoverable. It is likely that the actual remaining quantities recovered will exceed the estimated Proved Reserves. If probabilistic methods are used, there should be at least a 90 percent probability that the quantities actually recovered will equal or exceed the estimated Proved Reserves. "Probable Reserves" are those additional Reserves that are less certain to be recovered than Proved Reserves. It is equally likely that the actual remaining quantities recovered will be greater or less than the sum of the estimated Proved plus Probable (2P) Reserves. If probabilistic methods are used, there should be at least a 50 percent probability that the quantities actually recovered will equal or exceed the sum of the estimated 2P Reserves. "Possible Reserves" are those additional Reserves that are less certain to be recovered than Probable Reserves. It is unlikely that the actual remaining quantities recovered will exceed the sum of the estimated Proved plus Probable plus Possible (3P) Reserves. If probabilistic methods are used, there should be at least a 10 percent probability that the quantities actually recovered will equal or exceed the sum of the estimated 3P Reserves.

"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 which are not currently considered to be commercially recoverable due to one or more contingencies. Contingent Resources have an associated chance of development (economic, regulatory, market and facility, corporate commitment or political risks). The Contingent Resources estimates referred to herein have not been risked for the chance of development. There is no certainty that the Contingent Resources will be developed and, if developed, there is no certainty as to the timing of such development or that it will be commercially viable to produce any portion of the Contingent Resources.

"Prospective Resources" are those quantities of petroleum estimated, as of a given date, to be potentially recoverable from undiscovered accumulations by application of future development projects. Prospective Resources have both an associated chance of discovery (geological chance of success) and a chance of development (economic, regulatory, market, facility, corporate commitment or political risks). The chance of commerciality is the product of these two risk components. Unless otherwise indicated, the estimates referred to herein have not been risked for either the chance of discovery or the chance of development. There is no certainty that any portion of the Prospective Resources will be discovered. If a discovery is made, there is no certainty that it will be developed or, if it is developed, there is no certainty as to the timing of such development or that it will be commercially viable to produce any portion of the Prospective Resources.

Gross Block resource estimates presented herein represent the total volumes for the indicated reservoirs attributable to 100 percent of the relevant block, without any adjustment for the Company's working interest therein whereas the Working Interest (Gross) or Company Gross resource estimates presented represent the Company's 40 percent working interest (operating or non-operating) share before deduction of royalty petroleum, profit petroleum, production bonuses and capacity building support payments pursuant to the provisions of the applicable Production Sharing Contract.

Best Estimate (P50) or (2C) is considered to be the best estimate of the quantity that will actually be recovered. It is equally likely that the actual remaining quantities recovered will be greater of less than the best estimate. If probabilistic methods are used, there should be at least a 50 percent probability that the quantities actually recovered will equal or exceed the best estimate.

A barrel of oil equivalent (BOE) is determined by converting a volume of natural gas to barrels using the ratio of 6 thousand cubic feet (Mcf) to one barrel. BOEs may be misleading, particularly if used in isolation. A BOE conversion ratio of 6 Mcf:1 BOE is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.

The section "Statement of Reserves and Other Oil and Gas Information" (including Schedule A) contained in the Company's AIF dated March 16, 2016 filed on SEDAR at www.sedar.com, contains additional detail with respect to the Company's resource assessments and the estimates of net present value associated with its Reserves. This section includes the significant risks and uncertainties associated with the volume estimates and the recovery and development of the resources, the forecast prices and cost assumptions, descriptions of the applicable projects and FDPs and the specific contingencies which prevent the classification of the Contingent Resources as Reserves.

As indicated above, unless otherwise indicated, the estimates of Contingent Resources and Prospective Resources contained in this document are presented on an unrisked basis. Readers should refer to the AIF for the associated risked estimates of Contingent Resources and Prospective Resources. Such risked estimates are based upon the Company's estimates of chance of commerciality set forth therein which involves assessing various risks based upon a number of assumptions and other factors. While the Company believes that such estimates and underlying assumptions are reasonable, many of these assumptions are beyond the Company's control, are subject to change and may not, over time, prove to be accurate. As such, the actual level of various risks (including those currently identified and additional risks which may be identified in the future) could prove to be greater and the chance of commerciality lower than currently estimated and such differences could be material.

No additional projects have been defined at this time in respect of the Contingent Resources and Prospective Resources pertaining to other reservoirs for the Garmian and Kurdamir blocks since these reservoirs do not form part of the initial phases of the field development plans.

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