Africa Oil Second Quarter of 2013 Financial and Operating Results

VANCOUVER, BRITISH COLUMBIA--(Marketwired - Aug. 28, 2013) - Africa Oil Corp. (TSX VENTURE:AOI)(OMX:AOI) ("Africa Oil", "the Company" or "AOC") is pleased to announce its financial and operating results for the three and six months ended June 30, 2013.

On the back of the successful exploration activities in Kenya during 2012, the Company, together with its partners, continues to ramp up its exploration program in Kenya and Ethiopia. Entering the year, two Tullow-Africa Oil joint venture rigs were operating in Kenya and one joint venture rig was operating in Ethiopia. A fourth Tullow-Africa Oil joint venture rig has been secured and is expected to commence testing and drilling operations in Kenya on Blocks 10BB and 13T during October 2013. The Company, as operator, and its partner in Block 9 (Kenya) have secured a fifth rig, which will commence drilling operations in September 2013. In addition, the Company and its partners in Block 7/8 (Ethiopia) have secured a sixth rig, which will commence drilling operations in September 2013. For a period, the Company will have six drilling rigs operating and expects to exit the year with five rigs operating in the region. The Company plans to have drilled ten exploration wells and to have tested four wells across its exploration blocks during 2013 During the first half of the year, the Company completed a series of well tests at both Twiga South-1 and Ngamia-1 on Blocks 13T and 10BB in Kenya, respectively. These successful well tests confirmed over 5,000 barrels of oil per day ("bopd") flow potential per well and a doubling of our previous estimates of net oil pay. Ekales-1, the next exploration well in the Basin Bounding Fault Play and on trend with Ngamia-1 and Twiga South-1, commenced drilling in July. Transient Pressure Analysis has been conducted on the Twiga South-1 and Ngamia-1 well tests. No pressure depletion was recorded over the duration of the tests. Flow periods ranged from 0.5 to 2.5 days and build up periods ranged between 3 to 12 days. Upon completing testing operations at Ngamia-1 in Block 10BB, the Weatherford 804 rig mobilized to the Ekales-1 well in Block 13T. The Ekales prospect is located on the main basin bounding fault midway between the Ngamia-1 and Twiga South-1 discoveries and is targeting the same formations that were productive in these discoveries. The well spud in July and is expected to be completed around end September. In July, the Company announced a new major oil discovery at Etuko-1. Etuko-1 is located 14 kilometers east of Twiga South-1 in Block 10BB and is the first test of the Basin Flank Play in the eastern part of the Basin. The well encountered approximately 40 meters of net oil pay in the Auwerwer and Upper Lokhone targets and approximately 50 meters of additional potential net pay in the Lower Lokhone interval. The well will be tested later in the year. In July, the Company reported that the Sabisa-1 well on the South Omo Block in Ethiopia, the most northerly well drilled on the Tertiary rift trend to date, had confirmed a viable hydrocarbon system with oil and heavy gas shows. Based on the encouragement of the results, the decision was made to drill the Tultule-1 as the next well on the South Omo Block. This well is expected to spud around the end August. In the first quarter of 2013, the Company and its operating partners on Block 10A completed drilling the Paipai-1 exploration well. The Paipai-1 well tested a large four-way closed structure with Cretaceous-age sandstone targets at multiple depths. Paipai-1 spudded in September 2012 and completed drilling in the first quarter of 2013 to a total depth of 4,255 meters. Light hydrocarbons were encountered while drilling a 55 meter thick gross sandstone interval. Attempts to sample the reservoir fluid were unsuccessful and the hydrocarbons encountered while drilling were not recovered to surface. The Company and its partners were unable to test the well at the time due to the unavailability, in country, of testing equipment capable of handling the higher reservoir pressures encountered at this depth. As a result, the well has been temporarily suspended pending further data evaluation. The Company and its partner on Block 9 are currently planning to drill one exploration well in 2013. Block 9 is in the Cretaceous rift basin on trend with the South Sudan oil fields and the play concept was confirmed by the recent Paipai-1 well drilled in Block 10A. Two major prospects, Bahasi-1 and Sala-1, with large volume potential have been identified. The Company, as operator, and its partners in Block 9 have completed construction of the access road and well site for the Bahasi-1 exploration well. The Greatwall GW190 rig has commenced mobilization to site and the well is expected to spud in September. The Company and its partners continue to focus on the El Kuran oil accumulation on Block 8, discovered in the early 1970's. After completing reservoir characterization studies, the Company focused efforts on testing and completion strategies for producing commercial quantities of oil and gas. The Company and its joint operating partners on Blocks 7/8 (New Age operated) are planning to drill and test the El Kuran-3 appraisal well. The well site has been constructed, erection of the rig is ongoing at site and the well is expected to spud in September 2013. The Company continues to actively acquire, process and interpret 2D seismic over Blocks 10BA, 10BB, 12A, 13T and South Omo. In addition, the Company and its partner in Blocks 10BB and 13T will mobilize a 3D seismic crew to complete a 550 square kilometer 3D seismic survey over the Ngamia and Twiga structures later in 2013. In first quarter of 2013, the Company executed a PSC for the Rift Basin Area in Ethiopia. Located north of the South Omo Block, the Rift Basin Area covers 42,519 square kilometers. This block is on trend with highly prospective blocks in the Tertiary rift valley including the South Omo Block in Ethiopia, and Kenyan Blocks 10BA, 10BB, 13T, and 12A. The Company commenced acquiring a Full Tensor Gradiometry survey in May 2013, which is approximately 70% complete, and is conducting an exhaustive environmental and social impact assessment over the block in preparation for a seismic program in 2014. Africa Oil ended the quarter in a strong financial position with cash of $179.5 million and working capital of $141.2 million.

Keith Hill, President and CEO, commented, "Africa Oil is very encouraged with the results of our first three exploration wells in the Lokichar basin. Our fully funded 2013 work program is focused on drilling and testing multiple wells in the Lokichar sub-basin in Kenya in an effort to reach commercial thresholds and on drilling multiple potential basin-opening wells across its vast East African exploration acreage."

Second Quarter 2013 Financial and Operating HighlightsConsolidated Statement of Net Income (Loss) and Comprehensive Income (Loss)(Thousands of United States Dollars)Three months
ended
June 30,
2013Three months
ended
June 30,
2012Six months
ended
June 30,
2013Six months
ended
June 30,
2012Stock exchange and filing feesImpairment of intangible exploration assetsNet income (loss) and comprehensive income (loss)Net income (loss) and comprehensive income (loss) attributable to non-controlling interestNet loss and comprehensive loss attributable to common shareholdersNet loss attributable to common shareholders per shareWeighted average number of shares outstanding for the purpose of calculating earnings per share

Operating expenses increased $3.8 million for the three months ended June 30, 2013 compared to the prior year due mainly to an increase of $6.5 million in stock-based compensation relating to the 5,673,500 options granted in the current period. The increase was offset partially by a decrease of $3.1 million in professional fees due to finder fees paid in shares during the second quarter of 2012. The remaining $0.4 million increase can be attributed to increased salary and travel related costs associated with increased headcount and operational activity.

Operating expenses increased $1.2 million for the six months ended June 30, 2013 compared to the prior year due mainly to an increase of $6.6 million in stock-based compensation relating to the 5,673,500 options granted in the current period. The increase was offset by a decrease of $3.2 million in professional fees due to finder fees paid in shares and $3.1 million in impairment of intangible exploration assets relating to the abandonment of Blocks 7 and 11 in Mali during the prior period. The remaining $0.8 million increase can be attributed to increased salary and travel related costs associated with increased headcount and operational activity.

Financial income and expense is made up of the following items:

Three months
ended
June 30,
2013Three months
ended
June 30,
2012Six months
ended
June 30,
2013Six months
ended
June 30,
2012Fair value adjustment - warrants

The loss on revaluation of marketable securities is the result of a decrease in the value of 10 million shares held in Encanto Potash Corp which were acquired as part of the acquisition of Lion. These shares were sold during the first quarter of 2012.

At June 30, 2013, nil warrants were outstanding in AOC and 53.4 million warrants were outstanding in Horn. AOC holds 13.3 million of the warrants outstanding in Horn. The Company recorded a $0.2 million gain on the revaluation of warrants for the three months ended June 30, 2013 and a $2.9 million gain for the six months ended June 30, 2013, due to a reduction in the volatility of the shares of Horn combined with a reduction in the remaining life of the warrants. The Company will incur fair market value adjustments on the Horn warrants until they are exercised or they expire (43,868,527 expire September 20, 2013, 9,375,000 expire June 8, 2014, 156,248 expire June 11, 2014, and 15,000 expire June 18, 2014).

Interest income increased in the first six months of 2013 due to a significant increase in cash late in the fourth quarter of 2012 as a result of cash received from the non-brokered private placement in December of 2012.

The foreign exchange gains and losses are the direct result of changes in the value of the Canadian dollar in comparison to the US dollar. The Company's cash holdings are primarily in US and Canadian currency.

(Thousands United States Dollars)Accounts payable and accrued liabilitiesEquity attributable to common shareholders

The increase in total assets from December 31, 2012 to June 30, 2013 is primarily attributable to intangible asset expenditures incurred during the quarter in Kenya, Ethiopia and Puntland (Somalia).

Consolidated Statement of Cash Flows(Thousands United States Dollars)Three months
ended
June 30,
2013Three months
ended
June 30,
2012Six months
ended
June 30,
2013Six months
ended
June 30,
2012Cash flows provided by (used in):Net income (loss) and comprehensive income (loss) for the periodImpairment of intangible exploration assetsFair value adjustment - warrantsUnrealized foreign exchange lossChanges in non-cash operating working capitalProperty and equipment expendituresIntangible exploration expendituresProceeds from sale of marketable securitiesChanges in non-cash investing working capitalDeposit of cash for bank guaranteeEffect of exchange rate changes on cash and cash equivalents denominated in foreign currencyDecrease in cash and cash equivalentsCash and cash equivalents, beginning of periodCash and cash equivalents, end of period

The decrease in cash for the three and six months ended June 30, 2013 is mainly the result of intangible exploration expenditures and cash-based operating expenses.

Consolidated Statement of Equity(Thousands United States Dollars)Shares to be issued in lieu of professional feesNet loss and comprehensive loss attributable to common shareholdersTotal equity attributable to common shareholdersNon-controlling interest on issuance of Horn sharesNet income (loss) and comprehensive income (loss) attributable to non-controlling interest

The Company's consolidated financial statements, notes to the financial statements, management's discussion and analysis for the three and six months ended June 30, 2013 and the 2012 Annual Information Form have been filed on SEDAR (www.sedar.com) and are available on the Company's website (www.africaoilcorp.com).

Outlook

The Company is significantly increasing the pace of exploration. For a period during the last half of the year, the Company will have six drilling rigs operating and expects to exit the year with five rigs operating.

The Ngamia-1, Twiga South-1 and Etuko-1 light oil discoveries in the Lokichar sub-basin, combined with positive results from reservoir analysis and flow rate tests at Ngamia-1 and Twiga South-1, has led to a significant increase in the pace of exploration focused on tertiary rift basins. The Company and its joint venture partners in the tertiary rift play in east Africa plan to have four rigs operating by the end of 2013. The near term focus of these rigs is to continue drilling and testing wells in the Lokichar sub-basin in Kenya with improved efficiencies in an effort to continue building its contingent resource base, and to drill potential basin-opening wells in the Turkana, Chew Bahir, and Kerio basins in the tertiary rift play within Kenya and Ethiopia. Resources discovered to date are of a scale that the Tullow-Africa Oil joint venture partnership will initiate discussions with the Government of Kenya and other relevant stakeholders to consider development options. These discussions include consideration of a "start-up phase" oil production system with potential to deliver significant production rates with oil export via road or rail in advance of a full-scale pipeline development. The Company and its partners will continue to acquire seismic data throughout the tertiary rift in Kenya and Ethiopia in an effort to add to its existing portfolio of drill-ready prospects.

The Company and its operating partner in Block 9 in Kenya are currently mobilizing Greatwall GW190 rig to drill the Bahasi-1 exploratory well. This well which is planned to spud in September will be drilled on a large anticlinal structure targeting tertiary and cretaceous sandstones where six billion barrels of oil was discovered along trend in Sudan in a similar geologic setting. A follow-up well is also being considered in early 2014 in Block 9. The Company and its operating partners in Blocks 7/8 in Ethiopia are currently mobilizing a rig to drill a well to appraise reservoir characteristics of Jurassic carbonates on the El Kuran oil accumulation. The main focus of this well which is expected to spud in September, is to establish commercial rates with acidizing, fraccing and horizontal sidetracks being considered.

Based on the encouragement provided by the Shabeel wells, the Company and its partners entered the next exploration period in both the Dharoor Valley and Nugaal Valley PSAs which carry a commitment to drill one well in each block within an additional three year term ending October 2015. The current operational plan is to contract a seismic crew to acquire additional data in the Dharoor Valley block and to hold discussions with the Puntland Government regarding drill ready prospects in the Nugaal Valley block. The focus of the Dharoor Valley block seismic program will be to delineate new structural prospects for the upcoming drilling campaign. Horn has been in discussion with potential joint venture partners and is reviewing new venture opportunities in the region.

Africa Oil Corp. is a Canadian oil and gas company with assets in Kenya and Ethiopia as well as Puntland (Somalia) through its 45% equity interest in Horn Petroleum Corporation. Africa Oil's East African holdings are in within a world-class exploration play fairway with a total gross land package in this prolific region in excess of 250,000 square kilometers. The East African Rift Basin system is one of the last of the great rift basins to be explored. Two new significant discoveries have been announced in the Lokichar basin in which the Company holds a 50% interest along with operator Tullow Oil plc. The Company is listed on the TSX Venture Exchange and on First North at NASDAQ OMX-Stockholm under the symbol "AOI".

FORWARD-LOOKING STATEMENTS

Certain statements made and information contained herein constitute "forward-looking information" (within the meaning of applicable Canadian securities legislation). Such statements and information (together, "forward looking statements") relate to future events or the Company's future performance, business prospects or opportunities. Forward-looking statements include, but are not limited to, statements with respect to estimates of reserves and or resources, future production levels, future capital expenditures and their allocation to exploration and development activities, future drilling and other exploration and development activities, ultimate recovery of reserves or resources and dates by which certain areas will be explored, developed or reach expected operating capacity, that are based on forecasts of future results, estimates of amounts not yet determinable and assumptions of management.

All statements other than statements of historical fact may be forward-looking statements. Statements concerning proven and probable reserves and resource estimates may also be deemed to constitute forward-looking statements and reflect conclusions that are based on certain assumptions that the reserves and resources can be economically exploited. Any statements that express or involve discussions with respect to predictions, expectations, beliefs, plans, projections, objectives, assumptions or future events or performance (often, but not always, using words or phrases such as "seek", "anticipate", "plan", "continue", "estimate", "expect, "may", "will", "project", "predict", "potential", "targeting", "intend", "could", "might", "should", "believe" and similar expressions) are not statements of historical fact and may be "forward-looking statements". Forward-looking statements involve known and unknown risks, uncertainties and other factors that may cause actual results or events to differ materially from those anticipated in such forward-looking statements. The Company believes that the expectations reflected in those forward-looking statements are reasonable, but no assurance can be given that these expectations will prove to be correct and such forward-looking statements should not be unduly relied upon. The Company does not intend, and does not assume any obligation, to update these forward- looking statements, except as required by applicable laws. These forward-looking statements involve risks and uncertainties relating to, among other things, changes in oil prices, results of exploration and development activities, uninsured risks, regulatory changes, defects in title, availability of materials and equipment, timeliness of government or other regulatory approvals, actual performance of facilities, availability of financing on reasonable terms, availability of third party service providers, equipment and processes relative to specifications and expectations and unanticipated environmental impacts on operations. Actual results may differ materially from those expressed or implied by such forward-looking statements.

ON BEHALF OF THE BOARD

"Keith C. Hill", President and CEO

Africa Oil's Certified Advisor on NASDAQ OMX First North is Pareto Öhman AB.

Neither the TSX Venture Exchange nor its Regulation Services Pareto Provider Öhman (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this release.

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Douglas Channel LNG Project, British Columbia

HAMILTON, BERMUDA--(Marketwired - Aug 30, 2013) - Further to recent announcements regarding the Douglas Channel LNG Project, a clarification press release has been issued by the Project Partners and is attached below for reference.

August 30, 2013The Board of DirectorsGolar LNG LimitedHamilton, Bermuda.Questions should be directed to:Golar Management Limited - +44 207 063 7900Doug Arnell - Chief Executive OfficerBrian Tienzo - Chief Financial OfficerStuart Buchanan - Investor Relations

BCLNG Release - August 30 2013: http://hugin.info/133076/R/1726437/576077.pdf

This announcement is distributed by Thomson Reuters on behalf of Thomson Reuters clients. The owner of this announcement warrants that: (i) the releases contained herein are protected by copyright and other applicable laws; and (ii) they are solely responsible for the content, accuracy and originality of the information contained therein.

Source: Golar LNG via Thomson Reuters ONE [HUG#1726437]

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ChemSW to Sponsor BLR Webcast on Achieving Regulatory Chemical Compliance: Strategies & Approaches That Reduce Risk & Lower Costs

SOURCE: ChemSW, Inc.

FAIRFIELD, CA--(Marketwired - Aug 30, 2013) - ChemSW, Inc. will present a Business & Legal Reports (BLR) webcast on the "Achieving Regulatory Chemical Compliance: Strategies & Approaches that Reduce Risk & Lower Costs" on Wednesday, September 18, 2013 from 11:00am-12:00pm PT / 2:00pm-3:00pm ET. Register at http://webcasts.blr.com/SafetyDailyAdvisor/chemsw/chemical-compliance.aspx.

As most EHS managers know, compliance with many regulations on OSHA, SARA, TSCA, hazard communications, hazardous and solid waste -- and many more -- require you to have a detailed understanding of the materials that you are using in your facility. But, it goes much further than that. It is also necessary to have a detailed understanding of the quantity and attributes of the chemicals that you store, use, and dispose.

Compliance with most of these regulations is just not possible without a thorough understanding of the data on "what materials" and "how much." Trying to manage these two components manually and assure compliance is nearly impossible in the existing and complex regulatory reality.

Join us on September 18 for a free 60-minute webinar on how to achieve regulatory compliance for the regulated chemicals on your site. Our speakers will provide you with the latest on regulatory requirements impacting chemical use and storage, best practices for maximizing chemical inventory management compliance at your organization, and much, much more!

Attendees will learn:

A review of the general developments and regulatory requirements concerning chemical management Regulatory requirements that impact a company storing or utilizing chemicals as well as associated chemical waste The challenges you could face if you continue to use common methods to maintain compliance Best practices and management strategies to maximize chemical inventory management compliance  The true ROI of chemical inventory management and compliance, including costs to the company and the benefits of streamlining chemical inventory workflows

Hosted and moderated by BLR, the webinar will feature in-depth presentations by Laura Casey, Certified Safety Professional, and Anne Sefried, Sr. Inventory Consultant at ChemSW.

REGISTER NOW at
http://webcasts.blr.com/SafetyDailyAdvisor/chemsw/chemical-compliance.aspx

About BLR
Business & Legal Reports (BLR) has been helping HR, Safety and Environmental professionals with legal compliance and professional support resources for over 25 years. Employers know that they can count on BLR's compliance and training products to keep them out of legal trouble. For more information, visit http://www.blr.com.

About ChemSW
Founded over two decades ago, ChemSW is a leading provider of chemical and biochemical inventory management systems, MSDS systems, safety inspection software, and other chemistry laboratory software and services. ChemSW's wide range of products enables organizations to efficiently manage assets and processes. ChemSW supports over 15,000 customers in more than 40 countries throughout the world. For more information, visit www.ChemSW.com or call +1 707-864-0845.

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Elumelu Broadens Oil and Gas Focus, Expands Into West African Offshore Services

Heirs Holdings Has Acquired Significant Stake in Seadrill Mobil Units (Nigeria) Limited, a West African Affiliate of NY Listed Global Offshore Drilling Company, Seadrill

LAGOS, NIGERIA--(Marketwired - Aug 29, 2013) - Tony O. Elumelu's pan-African investment vehicle, Heirs Holdings, today announced a substantial investment in Seadrill Mobil Units (Nigeria) Limited, an affiliate of one of the world's leading offshore deepwater drilling companies, Seadrill. Elumelu has been appointed as chairman of the Board of Seadrill Mobil Units.

The investment is further evidence of Elumelu's strategy of increasing African businesses participate across the oil and gas value chain, and complement existing interests in oil and gas production and exploration. Seadrill, the world's leading offshore driller is listed on both the New York and Oslo stock exchanges, operating the second largest ultra-deepwater fleet and largest premium jackup fleet in the industry with 7,500 staff in 15 countries.

Commenting on the investment, Elumelu said, "Seadrill is a significant player in the oil and gas space, with a strong track record and one of the most respected names in the industry. The partnership makes strong commercial sense, bringing together a major global player and a leading African participant in the oil and gas industry. Successful development of Nigeria's deep water oil and gas fields is of strategic importance for our country. This is an important part of our own approach of creating synergistic added value investment across the energy sector, from extraction to processing and perhaps most importantly for Nigeria, industrial production and power generation."

Commenting further, Elumelu said, ''This partnership sets the stage for greater development in our energy sector, driven by local talent and should serve as a model for further, genuine, indigenous participation, creating both economic and social impact."

Seadrill Mobil Units (Nigeria) Limited, Director Svend Anton Maier added, "The partnership with Heirs Holdings creates the right mix of global technical expertise, backed by operational excellence and sound financial management to the Nigerian market. It positions the company as a local industry leader and a truly indigenous player."

Heirs Holdings makes proprietary investments in strategic sectors throughout Africa. Through affiliates Tenoil Petroleum & Energy Services; and Transcorp Energy -- established to lead Transcorp's focus on the energy sector, Heirs Holdings has already made significant commitments to the oil exploration and production sector, through the acquisition of OPL 281, an onshore oil field with substantial gas reserves, by Transcorp and Tenoil's development of OPL 2008, which is intended to enter production in 2014.

About Heirs Holdings
Heirs Holdings is a pan-African proprietary investment company driving Africa's development. We are active long-term investors who specialise in building businesses and corporate turnaround. We aim to transform the companies in which we invest and grow them into businesses that last. We invest in Africa to create value for our shareholders and partners, and to create economic prosperity and social wealth for the continent. Our investments in power, financial services, oil and gas, real estate and hospitality, agri-business and healthcare are helping to build economies, create jobs, drive prosperity and ultimately transform the lives of ordinary Africans in Africa.

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Detector Announces Filing of Second Quarter, 2013 Interim Financial Statements

CALGARY, ALBERTA--(Marketwired - Aug. 29, 2013) - Detector Exploration Ltd. (TSX VENTURE:DEX) ("Detector") announces that Detector has filed (through SEDAR) Detector's:

(a) second quarter ended June 30, 2013 unaudited financial statements,

(b) second quarter report to the Shareholders, operations review (including management discussion and analysis).

Copies of all of these materials are available for viewing by electronic means from the SEDAR web site (www.sedar.com).

Detector is an oil and gas corporation whose shares are listed for trading on TSX Venture Exchange Inc. under the symbol DEX.

As of August 29, 2013 Detector has outstanding 11,918,701 Common Shares. Detector has determined that Detector's "public float" (the number of shares outstanding not held by directors, officers, promoters, 10% shareholders or their affiliates, spouses, and other associates and not under any hold period or escrow restrictions) is 5,589,752 based on information provided to Detector by its insiders.

The officer responsible for issuance of this press release and who may be contacted for further information is:

Ronald E. Alexander, PresidentSuite 1100, 540 - 5th Avenue S.W.

NEITHER 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.

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Santa Maria Petroleum Inc. Announces Second Quarter 2013 Results

CALGARY, ALBERTA--(Marketwired - Aug. 29, 2013) -

NOT FOR DISTRIBUTION TO U.S. NEWS WIRE SERVICES OR FOR DISSEMINATION IN THE U.S.

Santa Maria Petroleum Inc. (formerly Quetzal Energy Ltd.) (TSX VENTURE:SMQ) announces its unaudited results for the three and six months ended June 30, 2013.

HIGHLIGHTS DURING THE THREE MONTHS ENDED JUNE 30, 2013

On June 7, 2013 Santa Maria announced that it had completed the sale of its 25% oil and gas interest in the Canaguaro Block to Petrominerales Ltd. ("Petrominerales") (TSX:PMG); the transaction was completed on June 7, 2013. Petrominerales paid Santa Maria a total of $US6.0 million in cash for its 25 per cent private participating interest. Certain customary post-completion price adjustments will be completed and all vendor liabilities outstanding on that date will be paid by the end of September 2013. The transaction was first announced on May 6, 2013. On June 13, 2013 Santa Maria remitted $1,875,000 to the operators of Block 21 in Colombia as the third and final installment pursuant to the Amending Agreement to the original Participation Agreement for Block 21. The Company has satisfied its financial obligations in respect of this block and no further funding is required. On February 26, 2013 the operator of Block 21 commenced drilling the Calacho-1 well, the first exploration well on this block and reached total depth of 7,000 feet on March 2, 2013. On March 14, 2013 the operator of Block 21 commenced drilling the Rocamao well, the second exploration well on this block and reached total depth of 7,870 feet on March 27, 2013. Both of these wells were tested during the second quarter of 2013.

The C7 formation in the Calacho No. 1 well was tested. During the test period the C7 formation produced a total of 5,857 barrels of fluid, consisting of 5,669 barrels of water and 188 barrels of 35 degree API oil. The maximum fluid production rate was approximately 1,450 barrels per day. The testing program was ended when the water cut reached 100%. With no further oil production, the operator made the decision to abandon the well.

The C7 formation in the Rocamao No. 1 well was also tested. The C7 formation produced 64 barrels of water in 3 hours at rates that fluctuated between 192 and 336 barrels of fluid per day. Total testing resulted in the production of 329 barrels of water with no oil produced and the decision was made by the operator to abandon the well. With no oil produced, the operator made the decision to abandon the well.

With the abandonment of both the Calacho No. 1 well and the Rocamao No. 1 well, Santa Maria Santa Maria informed the operator that it would not exercise its option to carry on with an interest in the block.

At the annual and special general meeting held in Toronto, Ontario on June 27, 2013 the shareholders approved the continued appointments of Mr. Ron MacMicken, Mr. Andrew DeFrancesco, Mr. Gerry Feldman, Mr. Steve VanSickle and Mr. Doug Manner to the board of directors. The shareholders also confirmed the appointment of MNP LLP as the Company's auditor.

Forward Looking Statements - Certain information set forth in this news release may contain forward-looking statements that involve substantial known and unknown risks and uncertainties. These forward-looking statements are subject to numerous risks and uncertainties, certain of which are beyond the control of Quetzal, including, but not limited to the impact of general economic conditions, industry conditions, volatility of commodity prices, risks associated with oil and gas activities, currency fluctuations, dependence upon regulatory approvals, the availability of future financing and exploration risk. Readers are cautioned that the assumptions used in the preparation of such information, although considered reasonable at the time of preparation, may prove to be imprecise and, as such, undue reliance should not be placed on forward-looking statements.

Neither 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.

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Golar LNG Limited Dividend Information

HAMILTON, BERMUDA--(Marketwired - Aug 29, 2013) - Reference is made to the second quarter 2013 report released on August 29, 2013. Golar LNG will be trading ex-dividend of a total dividend of $0.45 per share on September 11, 2013. The record date is September 13, 2013, and the dividend will be paid on or about September 26, 2013.

Golar LNG Limited

Hamilton, Bermuda

August 29, 2013

This announcement is distributed by Thomson Reuters on behalf of Thomson Reuters clients. The owner of this announcement warrants that:

(i) the releases contained herein are protected by copyright and other applicable laws; and

(ii) they are solely responsible for the content, accuracy and originality of the information contained therein.

Source: Golar LNG via Thomson Reuters ONE

[HUG#1725954]

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Alexander Energy Ltd. Announces Proposed Private Placement of Common Shares

CALGARY, ALBERTA--(Marketwired - Aug. 29, 2013) - Alexander Energy Ltd. ("Alexander" or the "Company") (TSX VENTURE:ALX) announced today its intention to complete a non-brokered private placement offering of common shares at a price of $0.15 per share, for gross proceeds of up to $1,300,000.

The closing of the offering is expected to occur on or about September 16, 2013 and is subject to regulatory approval, including approval of the TSX Venture Exchange. For further details on the offering, please contact the Company. The common shares issued in connection with the offering will be subject to a hold period of four months from the date of closing. The net proceeds from the offering will be used for general working capital purposes.

Forward-Looking Statements: This news release may contain certain forward-looking information. All statements included herein, other than statements of historical fact, is forward-looking information and such information involves various risks and uncertainties. There can be no assurance that such information will prove to be accurate, and actual results and future events could differ materially from those anticipated in such information. A description of assumptions used to develop such forward-looking information and a description of risk factors that may cause actual results to differ materially from forward-looking information can be found in the company's disclosure documents on the SEDAR website at www.sedar.com. The company does not undertake to update any forward-looking information except in accordance with applicable securities laws.

Neither TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this release.

To receive Press Releases and Corporate Updates directly via email send your email address to info@alexanderenergy.ca.

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Americas Petrogas Announces Second Quarter 2013 Results

Operating Netback(1) increases $13.7 million or 234%; Increase in net revenue by 75%; Net income of $5.1 million; $36.7 million of cash, investments and financial assets

CALGARY, ALBERTA--(Marketwired - Aug. 30, 2013) - Americas Petrogas Inc. ("Americas Petrogas" or the "Company") (TSX VENTURE:BOE) announces the Company continued to execute on its investment plan on its oil and gas properties in Argentina.

Summary Financial and Operational Highlights

Selected financial and operational information is outlined below and should be read in conjunction with the Company's condensed interim consolidated financial statements and the related Management's Discussion and Analysis ("MD&A") for the quarter, which have been filed on SEDAR under the Company's profile at www.sedar.com and are also available on the Company's website at www.americaspetrogas.com. All amounts are in Canadian dollars unless otherwise stated.

Net income: $5,121,233 in the second quarter of 2013 compared to a net loss of $4,731,206 for the equivalent period of 2012. This is the second consecutive quarter that the Company has reported profitability. Net revenue: increased by $6,371,527 or 75% compared to second quarter of 2012. Cash position: $36.7 million of consolidated cash, cash equivalents, short-term investments, and available-for-sale financial assets as of June 30, 2013. Oil sales volume: during the second quarter of 2013, the Company continued to produce and sell oil primarily from its Medanito Sur conventional block. During the second quarter of 2013, sales volume averaged 2,398 bopd (net), an increase of 70% over the second quarter of 2012 of 1,409 bopd (net). Operating netback: for the second quarter of 2013, operating netback (excluding Oil Plus benefits) was $44.72 per barrel and operating netback (including Oil Plus benefits) was $89.51 per barrel. For the second quarter of 2012, operating netback was $45.68 per barrel. Oil Plus benefits: during the second quarter of 2013, the Company recognized $11.2 million of Oil Plus benefits (related to production and reserve increases). This is in addition to $3.4 million recognized in the first quarter of 2013 and to $1.3 million recognized in the fourth quarter of 2012. Operating netback (including Oil Plus benefits)(1)Operating netback (excluding Oil Plus benefits) per barrel(1)Operating netback (including Oil Plus benefits) per barrel(1)Net income (loss) attributable to owners of the CompanyWeighted average number of common shares outstanding(3)Cash flow from operating activitiesAverage selling price per barrel

Notes:

"Operating netback" is a non-GAAP measure and is calculated as revenues from oil sales less royalties and production costs. Operating netback is used as an indicator of operating performance, profitability and liquidity. Operating netback (excluding Oil Plus benefits) excludes any Oil Plus benefits credited to production costs. Operating netback (including Oil Plus benefits) is net of any Oil Plus benefits credited to production costs. Operating netback does not have a standardized meaning prescribed by IFRS. It is unlikely for non-GAAP measures to be comparable to similar measures presented by other companies. For the three months ended June 30, 2013, operating netback including Oil Plus benefits was $19,535,145 (calculated as gross oil sales revenue of $17,224,255 less royalties of $2,368,597 plus production costs recovery of $4,679,487). For the three months ended June 30, 2012, operating netback was $5,855,237 (calculated as gross oil sales revenue of $9,729,829 less royalties of $1,245,698 and production costs of $2,628,894). For the six months ended June 30, 2013, operating netback including Oil Plus benefits was $32,701,960 (calculated as gross oil sales revenue of $33,673,901 less royalties of $4,471,378 plus production costs recovery of $3,499,437). For the six months ended June 30, 2012, operating netback was $12,937,395 (calculated as gross oil sales revenue of $21,357,636 less royalties of $3,789,881 and production costs of $4,630,360). "Funds flow from operations" is an additional GAAP measure because it is presented in the consolidated statement of cash flows. Funds flow from operations and funds flow from operations per share are used to analyze operating performance and liquidity. Funds flow from operations is calculated as net cash generated from (used by) operating activities (as determined in accordance with IFRS) before changes in non-cash balance sheet operating items. Funds flow from operations per share is calculated by dividing funds flow from operations by the weighted average number of shares outstanding. Funds flow from operations should not be considered an alternative to, or more meaningful than net cash generated from (used by) operating activities as determined in accordance with IFRS. Funds flow from operations per share should not be considered an alternative to, or more meaningful than earnings (loss) per share as determined in accordance with IFRS. Diluted weighted average number of common shares outstanding is computed by adjusting basic weighted average number of common shares outstanding for dilutive instruments. The number of shares included with respect to options, warrants and similar instruments is computed using the treasury stock method, which assumes any proceeds received by the Company upon exercise of the in-the-money instruments would be used to repurchase common shares at the average market price for the period. For the three and six months ended June 30, 2013, 1,936,583 (three months ended June 30, 2012 - 8,372,168) and 3,359,445 (six months ended June 30, 2012 - 9,970,025) common shares were deemed to be issued for no consideration in respect of options. Working capital is a non-GAAP measure and is calculated as current assets less current liabilities. Working capital is used to assess liquidity general financial strength. Working capital does not have a standardized meaning prescribed by IFRS. It is unlikely for non-GAAP measures to be comparable to similar measures presented by other companies. Working capital should not be considered an alternative to, or more meaningful than current assets or current liabilities as determined in accordance with IFRS.

Second Quarter Highlights and Recent Developments

Ryder Scott Company estimated that the Company has 56.1 Billion Barrels of Oil Equivalent ("BOE") initially in place and 8.3 Billion BOE Recoverable in the Company's nine unconventional shale oil and shale gas properties. The report only considered the Vaca Muerta, Agrio and Los Molles shales. The report did not consider additional zones of interest such as the Quintuco, Tordillo, Mulichinco and others. During the second quarter of 2013, Petrogas Argentina obtained two loans from the Industrial and Commercial Bank of China (Argentina) S.A. in the total amount of AR$50.0 million (approximately $9.5 million). Nine (9) conventional wells were drilled during the second quarter of 2013. Earlier in 2013, drilling on Medanito Sur resulted in the discovery of new production areas, including El Alpataco, El Calden Este, Amilcar and La Meseta. In total, twenty (20) conventional wells were drilled in the first half of 2013. As well, the Company invested $12.8 million in facilities and equipment during the first half of 2013. The Company, in conjunction with its partner, ExxonMobil, continued to conduct long-term production testing on the LTE.x-1 well and continued to analyze data relating to the ALL.x-1 well and ADA.x-1 well. During the second quarter of 2013, the Company made the necessary filings and received the necessary approvals to make a Normal Course Issuer Bid ("NCIB") to buy-back some of its common shares commencing on June 21, 2013 and terminating on June 20, 2014 or such earlier date as all shares which are subject to the NCIB are purchased. Up to the current date, the Company has bought back and cancelled 207,000 common shares for a total cost of approximately $185,000.

"We are pleased with our results this quarter, generating $19.5 million of operating netback at $89.51 per barrel, including Oil Plus benefits, and $5.1 million of net income," said Barclay Hambrook, President and Chief Executive Officer. Mr. Hambrook went on to say, "The results of the Ryder Scott Company report were excellent and this report clearly highlights the large upside potential of Americas Petrogas' Neuquen Basin blocks."

For further information regarding the Company's financial results, financial position and related changes, please see the consolidated financial statements and the related MD&A.

About Americas Petrogas Inc.

Americas Petrogas Inc. is a Canadian company whose shares trade on the TSX Venture Exchange under the symbol "BOE". Americas Petrogas has conventional and unconventional shale oil and gas and tight sands oil and gas interests in numerous blocks in the Neuquén Basin of Argentina. Americas Petrogas has joint venture partners, including ExxonMobil and Apache, on various blocks in the shale oil and gas corridor in the Neuquén Basin, Argentina. Americas Petrogas also owns an 80% interest in GrowMax Agri Corp., a private company involved in the exploration for near-surface potash, phosphates and other minerals, and potential development of a fertilizer project in Peru. Indian Farmers Fertiliser Co-operative Limited (IFFCO) owns a 20% interest in GrowMax Agri Corp. For more information about Americas Petrogas Inc., please visit www.americaspetrogas.com.

This Press Release contains forward-looking information including, but not limited to, the Company's goals and growth, estimates of reserves and resources, production and cash flows, new production areas on the Medanito Sur block, production testing of the LTE.x-1 well, analysis relating to the ALL.x-1 well and ADA.x-1 well, results of the Ryder Scott Company report, the large upside potential of Americas Petrogas' Neuquen Basin blocks, exploration, appraisal and development activities related to conventional and unconventional oil and gas, and other exploration, development and production activities in respect of the projects in Argentina and Peru. The recovery and resources estimates for the Company's properties described in this Press Release are estimates only and there is no guarantee that the estimated resources will be recovered. The actual resources for the Company's properties may be greater or less than those calculated. Additional forward-looking information is contained in the Company's MD&A for this quarter and the Company's Annual MD&A for December 31, 2012, and reference should be made to the additional disclosures of the assumptions, risks and uncertainties relating to such forward-looking information in those MD&A documents.

Forward-looking information is based on management's expectations regarding the Company's future growth, results of operations, production, future capital and other expenditures (including the amount, nature and sources of funding thereof), competitive advantages, plans for and results of drilling activity (including the timing, location, depth and the number of wells), environmental matters, business prospects and opportunities and expectations with respect to general economic conditions. Such forward-looking information reflects management's current beliefs and assumptions and is based on information, including reserves and resources information, currently available to management. Forward-looking information involves significant known and unknown risks and uncertainties. A number of factors could cause actual results, performance or achievements to differ materially from any future results, performance or achievements expressed or implied by the forward-looking information, including but not limited to, risks associated with the oil and gas industry (e.g. operational risks in development, exploration and production, delays or changes to plans with respect to exploration or development projects or capital expenditures; the uncertainty of reserve estimates; the uncertainty of geological interpretations; the uncertainty of estimates and projections in relation to production, costs and expenses and health, safety and environment risks, extensions of concessions and commitments), the risk of commodity price and foreign exchange rate fluctuations, the uncertainty associated with negotiating with foreign governments and third parties located in foreign jurisdictions and the risk associated with international activity.

Although the forward-looking information contained herein is based upon assumptions which management believes to be reasonable, the Company cannot assure investors that actual results will be consistent with this forward-looking information. This forward-looking information is made as of the date hereof and the Company assumes no obligation to update or revise this information to reflect new events or circumstances, except as required by law. Because of the risks, uncertainties and assumptions inherent in forward-looking information, prospective investors in the Company's securities should not place undue reliance on this forward-looking information.

The term BOE (barrels of oil equivalent) is used in this press release. All calculations converting natural gas to BOE have been made using a conversion ratio of six thousand cubic feet (six "Mcf") of natural gas to one barrel of oil, unless otherwise stated. The use of BOE may be misleading, particularly if used in isolation, as the conversion ratio of six Mcf of natural gas to one barrel of oil 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 crude 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.

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 THE RELEASE.

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Niko Provides Updates

CALGARY, ALBERTA--(Marketwired - Aug. 30, 2013) - Niko Resources Ltd. ("Niko" or the "Company") (TSX:NKO) is pleased to provide the following updates:

Farm-outs, Non-core Asset Dispositions, and Other Arrangements Update

Niko is pleased to announce that it has executed two sets of agreements which, subject to the required government approvals, will provide proceeds of nearly $40 million.

Farm-out of Grand Prix PSC in Madagascar

Niko has signed a definitive farm-out agreement under which OMV, an integrated international oil and gas company, will earn a 40% interest in the Grand Prix PSC in Madagascar, with Niko retaining a 35% working interest. Closing of the deal is subject to the approval of the Government of Madagascar.

Other Arrangements for Semai V and Kofiau PSCs in Indonesia

Niko has also signed a definitive agreement with Hess Corporation for certain consideration in exchange for assuming a 100% interest in the Semai V PSC, located offshore Papua province in eastern Indonesia. Two wells have been previously drilled in the block, Andalan 1 and 2, with one future commitment well yet to be drilled. Drilling results from these wells indicate hydrocarbon potential remaining on the block. The Company also signed an agreement to increase its working interest (effective prior to the drilling of the Elit-1 well discussed below) to 100% in the Kofiau PSC, also located offshore Papua province, for nominal consideration. The closings of these transactions are subject to the approval of the Government of Indonesia.

Indonesia Exploration Updates

Elit-1 Well

The Elit-1 well, located in the Kofiau PSC offshore Papua province in eastern Indonesia, has been drilled in water depth of 1,335 feet to a total depth of 3,915 feet in 9 days by Diamond Offshore's Ocean Monarch drilling rig, under budget and ahead of schedule. The well encountered 10 feet of gas at the top of a 90 foot sand package and has been plugged and abandoned.

Drilling Operations

Pending the Company's re-evaluation of its go-forward exploration capital spending priorities, the Company has decided to temporarily suspend its drilling program in Indonesia. The Company is working on various options to drill for third parties or to assign the contract for the Ocean Monarch rig and related service contracts to third parties for an extended period of time. The Ocean Monarch is being mobilized to the Makassar Strait area until the decision on the next drilling location has been finalized.

Financing Updates

Credit Facility

The Company is continuing its discussions with its credit facility syndicate banks regarding the re-determination of the borrowing base under its credit facility and is working with the banks on a deferral to September 30, 2013 for the re-determination date and a deferral to October 31, 2013 for any required adjustment to outstanding borrowings to reflect the new borrowing base.

Potential Refinancing of the Credit Facility

The Company is working on options to potentially refinance its credit facility to provide increased funding for its future capital programs.

Forward-Looking Information

Certain statements in this press release constitute forward-looking information. Specifically, this press release contains forward looking information relating to various governmental approvals, proceeds from various agreements, the Company's working interest in various PSCs, the re-determination of the Company's borrowing base under the credit facility and the re-financing of the Company's credit facility. These forward looking statements are based on certain key expectations and assumptions of management, including anticipated market conditions. The reader is cautioned that the assumptions used in the preparation of such forward looking information, although considered reasonable at the time of preparation, may prove to be incorrect and there can be no assurance that the expected proceeds from agreements will occur or occur on terms acceptable to the Company. Actual results achieved may vary from the information provided herein as a result of numerous known and unknown risks and uncertainties and other factors and such variations may be material. Such factors include, but are not limited to: risks associated with market conditions; risks associated with oil and gas operations including equipment failures or accidents; the ability of suppliers and third party contractors to meet commitments; pressure or irregularities in geological formations; and adverse weather conditions. Niko makes no representation that the actual results achieved during the forecast period will be the same in whole or in part as those forecast.

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WesternZagros Announces Second Quarter 2013 Operational and Financial Results

CALGARY, ALBERTA--(Marketwired - Aug. 29, 2013) -

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 second quarter ended June 30, 2013, and additional key highlights and activities to date. A summary of the activities, the financial statements the accompanying Management Discussion and Analysis ("MD&A") are available at www.westernzagros.com and on SEDAR at www.sedar.com.

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

"We're continuing testing in the Kurdamir-3 well to provide valuable information on the Kurdamir Discovery as we progress towards commerciality and to help us plan future well locations. In addition, our two Garmian wells, Baram-1 and Hasira-1, are drilling with completion anticipated in late Q4 2013 and early Q1 2014, respectively. Hasira-1 will help us in our development plans for our Sarqala Discovery. The timing of declaration of commerciality and submission of development plans are actively in discussion with our partners and will represent a major step for our Company. We have also completed our first 3D seismic program at Sarqala and the second, our North Garmian, is underway. This is a busy year for WesternZagros."

Exploration and Appraisal Operations - Kurdamir Block

Testing of the Oligocene reservoir in the Kurdamir-3 well is ongoing with final results anticipated in late third quarter 2013 or early fourth quarter 2014. As operator of the Kurdamir-3 well, Talisman (Block K44) B.V. ("Talisman") has conducted two DSTs in the deepest zones of the Oligocene reservoir at Kurdamir-3. Log and sample analysis obtained from testing to date has warranted the testing of two other intervals in the upper zones of the Oligocene reservoir. Interim test results from Kurdamir-3 have increased the risk associated with the undiscovered Prospective Resource assessment that the Company carries for the Kurdamir Oligocene reservoir. The acquisition of the Kurdamir Block 3D seismic survey, which comprised 184 square kilometers, has been completed in order to define more clearly the areal extent of the Oligocene, Eocene and Cretaceous reservoirs. Processing and interpretation of the data are currently underway with completion anticipated in the first quarter of 2014. The results will be utilized to select the location of the Kurdamir-4 well to further appraise the extent of the oil discovery in the Oligocene reservoir.

Exploration and Appraisal Operations - Garmian Block

The Baram-1 well was spudded on August 13, 2013 and is preparing to drill ahead after setting 20 inch casing at 816 metres. This well is exploring whether the Baram structure is a separate structure from Kurdamir or a potential extension of the oil leg discovered in the Oligocene reservoir of the Kurdamir structure onto the northern portion of the Garmian Block. The Company expects the well to be drilled to planned total depth of 3,800 metres by the end of 2013. If successful (the extension is confirmed and it is oil bearing) the Company believes that this could be the highest impact well of the 2013 drilling program, with the potential to add substantial contingent resources in both the Garmian Block and in the Kurdamir Block. The interim results of Kurdamir-3 testing increase the risk associated with the undiscovered Prospective resource assessment for the Baram-1 well. Alternatively, the Baram structure may be separated from the Kurdamir structure by a fault, in which case the Kurdamir-3 well results have no material impact on the chance of success of Baram-1. The Hasira-1 appraisal and exploration well is currently drilling ahead at 2,886 metres after setting 16 inch casing at 2,047 metres. The next casing point is planned for approximately 3,900 metres just above the Jeribe reservoir. The well is planned to drill to a total depth of approximately 4,100 metres in the Oligocene reservoir. WesternZagros plans to complete the well either in the Jeribe or the Oligocene reservoir depending on testing results. Hasira-1 is anticipated to be completed in late fourth quarter 2013 or early first quarter 2014. The acquisition phase of the 2D seismic survey over the Chwar and Alyan prospects and the 3D seismic survey over the Sarqala and Mil Qasim oil discoveries and the Zardi Complex prospect was completed on April 8, 2013, on time and on budget. Processing and interpretation of the data are currently underway and expected to be completed in the fourth quarter, 2013. The acquisition phase of the 3D seismic survey over the northern portion of the Garmian block commenced on August 6, 2013 in order to define more clearly the areal extent of the Baram and Qulijan structures. Acquisition is anticipated to be completed in the third quarter with processing and interpretation completed by the end of the year. The Company is also beginning to prepare for future exploration wells, with the Qulijan well site prepared and long lead items ordered. Preliminary interpretation and technical evaluations are underway of the Chwar Prospect in the southwest of the Garmian Block, the Alyan Prospect in the west of the Block and the Qula Prospect on the southeast of the Block, Qula is in close proximity to Genel Energy plc's Chia Surkh oil discovery on the adjacent block. The Company will determine its 2014 drilling program in the fourth quarter 2013.

Planning and Development (Garmian and Kurdamir Blocks)

Design work is underway on future development plans for the WesternZagros oil discoveries in the Sarqala and Kurdamir areas. On the Garmian Block, the preliminary engineering design of the Sarqala-1 first phase central processing facility with 20,000 bbl/d capacity is advancing. WesternZagros is in active discussions with its co-venturer Gazprom Neft Middle East B.V. ("Gazprom Neft") regarding the timing of the Declaration of Commerciality for the Sarqala discovery. WesternZagros and Gazprom Neft have formed a dedicated team to plan the phased development of the Sarqala Discovery. On the Kurdamir Block, Talisman has staffed a dedicated team which has commenced development planning and the joint venture has created a sub-committee to focus on designing the development plan for the Kurdamir Discovery. Subject to the extended test results from the Kurdamir-3 well and the interpretation of the 3D seismic, the Kurdamir Joint Venture is contemplating a Declaration of Commerciality for the Kurdamir structure by the second quarter of 2014. The Company and its co-venturers continue discussions with the Kurdistan Regional Government ("KRG") to advance plans for the utilization of natural gas from both the Garmian and Kurdamir Blocks. Gas conservation studies are ongoing for pipeline routing, gas re-injection options to maximize oil recovery, and options for temporary and permanent power generation.

Financing

On April 4, 2013 the Company completed a marketed private placement of 11,431,422 common shares with Crest Energy International LLC ("Crest") of Houston, USA, and Jasmine Capital (a wholly-owned subsidiary of Richard Chandler Corporation) at Cdn$1.25 per common share for gross proceeds of $14.1 million. This followed the non-brokered private placement of 51 million common shares at Cdn$1.25 per common share and the entering of a loan agreement with Crest for $57.5 million. The net proceeds of the marketed private placement of $13.5 million were used to repay $13.3 million of the principal amount of the loan from Crest plus $0.2 million of accrued interest. On June 18, 2013, the Company completed a non-brokered private placement of Cdn$70 million aggregate principal amount of 4.00% Convertible Senior Unsecured Notes of WesternZagros ("Convertible Notes") to investment funds managed by Paulson & Co. Inc. Effective June 28, 2013 the Company completed a second non-brokered private placement of Cdn$30 million aggregate principal amount of Convertible Notes. A portion of the proceeds from the private placements were used to repay the remaining Crest debt of $44.5 million plus accrued interest as per the terms of the loan agreement with the balance to be used to fund the Company's capital and operating activities. All of the Convertible Notes issued in the second quarter of 2013 have a face value of Cdn$1,000 per note, a coupon of 4 percent per annum, a maturity date of December 31, 2015 and are convertible into common shares of the Company ("Common Shares") at the option of the holder at a conversion price of Cdn$1.45 per share (subject to adjustment in certain events), representing a conversion premium of approximately 27 percent to the thirty day average price for the Common Shares prior to issuance of the Convertible Notes. As at June 30, 2013, WesternZagros had $167.4 million in working capital, excluding the $16.9 million additional non-current portion of the deposit held in trust pertaining to the drilling contract. The Company is fully funded for its currently planned activities.

Corporate

The Company is considering the optimal timing to pursue admittance to the Standard Listing segment of the Official List of the London Stock Exchange ("LSE") in order to provide access to an alternate market with a strong understanding of the Middle East and particularly Kurdistan focused companies. On June 3, 2013, Ms. Mary Benassi was appointed to the position of Vice President Human Resources with responsibility for WesternZagros's overall Human Resources function.

Outlook

In accordance with the Kurdamir and Garmian PSCs, the end of the exploration periods are September 1, 2014 and December 31, 2014, respectively, after which the development periods begin. On the Kurdamir Block, the Company's focus will continue to delineate the existing 943 MMBOE of unrisked gross contingent resources (combined mean estimate ("Gross Mean Contingent Resources") and an estimated 1.6 billion BOE of unrisked gross prospective resources (combined mean estimate) ("Gross Mean Prospective Resources"). On the Garmian Block, the Company's focus will be on exploration and appraisal drilling to delineate the following estimated Gross Mean Prospective Resources: 527 MMBOE on the Baram prospect and 463 MMBOE on the Sarqala Discovery. In addition, WesternZagros's work program on the Garmian Block over the next 18 months will also include exploration activities to rank, prioritize and drill the highest ranked additional prospects prior to the end of the exploration period. This ranking will be based on the results of the North and South Garmian Seismic Programs (2D and 3D), the 2013 drilling results from the Company's planned wells on the Garmian and Kurdamir Blocks and other operators' well results on neighbouring blocks. Possible prospects for future exploration drilling in 2014 include Qulijan, Qula, Chwar, and Alyan. At the same time, the Company has started discussions with its respective co-venturers with respect to timing of declaring commerciality and submitting development plans. Subject to the completion of the exploration and appraisal programs, WesternZagros anticipates issuing Declarations of Commerciality before the end of the Exploration period on the Kurdamir and Garmian Blocks of September 1, 2014 and December 31, 2014, respectively.

Kurdamir Block

The Company continues to work with the operator, Talisman, to appraise the giant Kurdamir discovery. Activities in the second half of 2013 will focus on further testing at Kurdamir-3, the processing and interpretation of the 3D seismic, analysis and integration into reservoir models of the data from Kurdamir-3 acquired to date (including cores, log data, oil samples, and water samples), and the preparation and planning required for a declaration of commerciality in 2014 and the start of field development. The remaining tests at Kurdamir-3 will be conducted on the upper part of porous zone of the Oligocene reservoir which was oil-bearing in Kurdamir-2 and which is more than 87 meters below the depths of the gas-oil contact as seen in Kurdamir-2. This testing is anticipated to be completed early in the fourth quarter.

Planned expenditures for the remainder of 2013 include approximately $12-$17 million for the Kurdamir-3 testing program (including the costs of DST#1 and #2 estimated at $7-8 million), $4 million for the remainder of Kurdamir 3D seismic program and processing costs, and $4-8 million for preparation and planning for declaration of commerciality and field development. Contingent projects during 2013 may also include $9 million for a potential Kurdamir-3 sidetrack.

Garmian Block

Sarqala-1 Extended Well Test ("EWT")

WesternZagros expects to recommence the EWT at Sarqala upon KRG approval to gain additional information in order to appraise the discovery for future development. Upon receipt of KRG approval, and the procurement of a suitable rig and tubular equipment, the Company also plans to complete a workover of the Sarqala-1 well in the first half of 2014 in order to allow future EWT production capability to increase beyond the current 5,000 bbl/d. Long lead items have been ordered for this workover.

Engineering work is also underway for permanent facilities to increase EWT production capability at Sarqala including gas conservation measures. In particular, preliminary engineering design of the Sarqala first phase permanent facilities with 20,000 bbl/d capacity is underway in readiness to request engineering procurement and construction tenders at the appropriate time. Work is continuing on opportunities to utilize the associated natural gas from any future crude oil production to minimize the flaring of natural gas.

Hasira-1 Exploration and Appraisal Well

The Hasira-1 appraisal and exploration well was spudded on June 6, 2013 and is currently drilling ahead at 2,886 metres after setting 16 inch casing at 2,047 metres. WesternZagros plans to complete the well either in the Jeribe or the Oligocene reservoir depending on drilling and testing results. Hasira-1 will appraise the extent of the oil leg previously encountered in the Jeribe reservoir, targeting 25-50 MMBOE of Gross Mean Prospective Resources, at the Sarqala-1 well and also to explore the deeper Oligocene reservoir, targeting a further 25-50 MMBOE of Gross Mean Prospective Resources. Significant oil shows were encountered in the Oligocene interval at Sarqala-1 but the Company was unable to evaluate them at that due to wellbore conditions. The Company expects Hasira-1 to take approximately seven months to drill.

Baram-1 Exploration Well

The Baram-1 well was spudded on August 13, 2013 to explore the potential extension of the oil leg discovered in the Oligocene reservoir of the Kurdamir structure onto the northern portion of the Garmian Block. The Company expects the well to reach the planned total depth of 3,800 metres by the end of 2013. If successful and it is oil bearing, the Company believes that this could be the highest impact well of the 2013 drilling program with the potential to add substantial contingent resources in both the Garmian Block and in the Kurdamir Block. The interim results of Kurdamir-3 testing increase the risk associated with the undiscovered Prospective resource assessment for the Baram-1 well. Alternatively, the Baram structure may be separated from the Kurdamir structure by a fault, in which case the Kurdamir-3 well results have no material impact on the chance of success of Baram-1.

The completion of either Baram-1 or Hasira-1 in 2013 would fulfill the Company's obligations under the second exploration sub-period of the Garmian PSC, prior to any extension of such sub-period.

Garmian Seismic Programs

WesternZagros has completed the acquisition phase of a 3D seismic appraisal survey over the Sarqala, Mil Qasim and adjacent Zardi Complex structures as well as the 2D seismic survey at the Chwar and Alyan prospects which are to the north and west-northwest of Sarqala to elevate these low risk, Jeribe oil opportunities to drill ready status. The Company will utilize the 3D information to optimize the number and placement of future appraisal and development well, improve its understanding of fracturing within these structures and further evaluate the Jeribe, Oligocene, Eocene and Cretaceous reservoirs on the southern portion of the Block.

The Company is conducting a 3D seismic program in the second half of 2013 over the northern portion of the Garmian Block targeting the Baram and Qulijan structures utilizing the seismic crew from the Kurdamir/Tophkana program. The 3D data over Baram will assist in determining whether Baram is an extension of the existing Kurdamir Oligocene discovery or a separate structure.

Planned expenditures for the remainder of 2013 include $20 million for the Hasira-1 well, $20 million for the Baram-1 well $4 million for the Sarqala planning and predevelopment activities, $ million for long leads for future wells, $10 million for the planned North Garmian 3D seismic program and $3 million for other costs.

This news release contains certain forward-looking information relating, but not limited, to operational information, future drilling and testing plans, seismic programs and the timing and costs associated therewith. Forward-looking information typically contains statements with words such as "anticipate", "plan", "estimate", "expect", "potential", "could", or similar words suggesting future outcomes. The Company cautions readers not to 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. In addition, the forward-looking information is made as of the date hereof, and the Company assumes no obligation to update or revise such to reflect new events or circumstances, except as required by law.

Forward-looking information is not based on historical facts but rather on management's current expectations and assumptions regarding, among other things, plans for and results of drilling activity and testing programs, future capital and other expenditures (including the amount, nature and sources of funding thereof), continued political stability, and timely receipt of any necessary government or regulatory approvals. 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 exploration; inherent uncertainties in interpreting geological data; changes in plans with respect to exploration or capital expenditures; interruptions in operations together with any associated insurance proceedings; the uncertainty of estimates and projections in relation to costs and expenses and health, safety and environmental risks), the risk of commodity price and foreign exchange rate fluctuations, the uncertainty associated with negotiating with foreign governments and risk associated with international activity. For further information on WesternZagros and the risks associated with its business, please see the Company's Annual Information Form dated March 22, 2013, which is available on SEDAR at www.sedar.com.

In addition, statements relating to "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. 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. "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. 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. "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 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. All resource estimates presented are gross volumes for the indicated reservoirs, without any adjustment for the Company's working interest or encumbrances. A barrel of oil equivalent (BOE) is determined by converting a volume of natural gas to barrels using the ratio of 6 million 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 Company's Statement of Oil and Gas Information contained in its Annual Information Form dated March 22, 2013 ("AIF") filed on SEDAR at www.sedar.com contains additional detail with respect to the resource assessments and includes the significant risks and uncertainties associated with the estimates and the recovery and development of the resources, and, in respect of contingent resources, the specific contingencies which prevent the classification of the resources as reserves. In addition, combined mean estimates of resources which are presented in this MD&A are an arithmetic sum of the mean estimates for individual reservoirs and each such individual mean estimate is the average from the probabilistic assessment that was completed for the reservoir. Readers should refer to the AIF for a detailed breakdown of the high (P10), low (P90) and best (P50) estimates for each of the individual reservoir assessments.

NEITHER THE TSX VENTURE EXCHANGE NOR ITS REGULATION SERVICES PROVIDER (AS THAT TERM IS DEFINED IN POLICIES OF THE TSX VENTURE EXCHANGE) ACCEPTS RESPONSIBILITY FOR THE ADEQUACY OR ACCURACY OF THIS RELEASE.

WESTERNZAGROS RESOURCES WAS RECOGNIZED AS A TSX VENTURE 50® COMPANY IN 2012 AND 2013. TSX VENTURE 50 IS A TRADE-MARK OF TSX INC. AND IS USED UNDER LICENSE.

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Hanwei Energy Services Announces Results of Annual General Meeting

VANCOUVER, BRITISH COLUMBIA--(Marketwired - Aug. 30, 2013) - Hanwei Energy Services Corp. (TSX:HE) ("Hanwei" or the "Company"), held its Annual General Meeting of Shareholders (the "Meeting") in Vancouver, British Columbia on August 29, 2013. During the course of the Meeting, all proposed resolutions were approved including the election of directors, the re-appointment of MNP LLP, Chartered Accountants as auditor of the Company, and the continuation of the incentive Stock Option Plan of the Company. A total of 22,070,223 shares were voted in person or by proxy at the Meeting.

The shareholders elected each of the Company's nominees for director as follows:

As of the close of the Meeting, the Company's board is constituted of a majority of independent directors, namely Joanne Yan, Malcolm Clay, William Paine, and Randall Smallbone.

At the first meeting of the newly constituted Board of Directors held immediately after the Meeting, the following individuals were re-appointed as officers of the Company: (a) Fulai Lang as Chairman of the Board, President and Chief Executive Officer, (b) Yucai (Rick) Huang as Chief Financial Officer, (c) Graham Kwan as Executive Vice President, Strategic Development and Corporate Affairs, and Corporate Secretary.

The Board of Directors also re-appointed Joanne Yan as Lead Director and reconstituted its standing board committees. The Audit Committee is comprised of Randall Smallbone (Chair), Malcolm Clay and Joanne Yan who are each independent directors. The Compensation/Corporate Governance Committee is comprised of Malcolm Clay (Chair), Fulai Lang, Joanne Yan, William Paine and Randall Smallbone, a majority of whom are independent directors. The Disclosure Committee is comprised of Graham Kwan (Chair), Fulai Lang, and Yucai (Rick) Huang.

About Hanwei Energy Services Corp.

Hanwei Energy Services Corp. is a world leader in the manufacturing of high pressure, fiberglass reinforced plastic ("FRP") pipe products, and associated technologies and services, for the international oil and gas and infrastructure industries. Hanwei serves major energy customers in the Chinese and global energy markets.

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Veraz Petroleum Announces Filing of First Quarter Financial Statements and Management's Discussion and Analysis

CALGARY, ALBERTA--(Marketwired - Aug. 29, 2013) - Veraz Petroleum Ltd. ("Veraz") (TSX VENTURE:VRZ.H) announces that it has filed its unaudited condensed interim consolidated financial statements and accompanying notes for the three month period ended March 31, 2013 and its related management's discussion and analysis with applicable Canadian securities regulatory authorities. Copies of these documents may be obtained through the Internet on the System for Electronic Document Analysis and Retrieval (SEDAR) at http://www.sedar.com/.

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.

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Blackdog Resources Ltd. Announces Intention to Purchase Two Light Oil Properties in Alberta for $13,000,000

CALGARY, ALBERTA--(Marketwired - Aug. 30, 2013) - Blackdog Resources Ltd ("Blackdog" or the "Company") (TSX VENTURE:DOG) is pleased to announce that it has signed two separate non-binding Letters of Intent (the "LOI's") with two separate arm's length vendors to purchase two light oil properties in Northern Alberta (the "Acquisitions"). Under the terms of the LOI's, Blackdog will purchase both properties for a cumulative total of $13,000,000 in cash. The properties ("Property A and Property B") currently produce between 260-275 boepd (97% light oil).

Blackdog intends to purchase the first property ("Property A") from a Public Company ("Pubco"). Property A has both Operated and Non Operated wells that the Company will purchase. On average the Company will have a 25-50% W.I. in the wells it is purchasing. Property A is located in a different area of Northern Alberta than Property B. The oil produced at Property A comes from 3 different formations, the Granite Wash, Gilwood and Slave Point. All of these oils are high quality light oils that demand prices very close to listed Edmonton Par pricing. The Company has identified multiple low cost, low risk re-entries into existing well bores where it expects to yield high returns for low capital investment.

Transaction Metrics of Property AProved Reserves (NPV10(BT))(1)Proved Plus Probable Reserves (NPV10(BT))(1)Edmonton Par Pricing for 2013(1)2013 Netbacks(3) at 2013 Forecasted Edmonton Par Price(1)Actual August 28, 2013 Edmonton Par Price(4)Derived from Pubco's (as defined below) December 31, 2012 independent reserves evaluation prepared by AJM Deloitte in accordance with National Instrument 51-101 ("NI 51-101") and the COGE handbook. An updated reserves evaluation for Property A will be obtained and prepared in accordance with NI 51-101.Based on July, 2013 field estimates provided by the vendors.Netbacks do not have a standardized meaning under GAAP. Netbacks are determined by deducting royalties, production expenses and transportation and selling expenses from oil and gas revenue. Netbacks are per boe measures used in operational and capital.Allocation decisions from Daily Oil Bulletin August 28, 2013.

Blackdog intends to purchase the second property ("Property B") from a Private Company ("Privco"). Property B is a 6% Non Operated Working Interest ("W.I.") in an emerging light oil play in Northern Alberta. Blackdog will be acquiring a full 6% W.I. in over 300 sections of land, all facilities, pipelines, seismic and other associated assets. The oil produced at this property is also a high quality Gilwood oil that demands prices very close to Edmonton Par pricing. Property B currently has over a dozen producing wells with all wells tied into pipelines for both oil and water shipping and disposal. The property is fully electrified resulting in very low operating costs. In excess of 30 possible future drilling locations have been identified by the Operator of the property. The current production from the property in July, 2013 based on field reports provided by Privco was 105 boepd (95% light oil). Blackdog will be obtaining a reserves evaluation report with respect to Property B prepared in accordance with NI 51-101 in due course.

David A. Corcoran, President of Blackdog stated, "Blackdog is very pleased to have identified and negotiated deals on both of these high quality light oil properties. The Company believes that by assembling multiple producing light oil properties with reduced risk but additional running room for growth and excellent financial metrics, it will be able to attract required funding from financial institutions and investors and enhance shareholder value. The successful closing of these Acquisitions would cause Blackdog to become a larger entity with higher rates of production, stronger cash flows and reserves and provide a clear roadmap for future growth."

Each of the Acquisitions remain subject to completion of due diligence, financing, board approval by both parties and the execution of definitive purchase and sale agreements, as well as approval by the TSX Venture Exchange. Blackdog intends to announce the details of the proposed financing for the Acquisitions in due course. Both Acquisitions are expected to be completed in October 2013.

About Blackdog

Blackdog is a junior oil and gas Company focused on light oil development in South East Saskatchewan and Alberta. The Company currently has 27,166,212 common shares outstanding.

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 the accuracy of this release.

Certain information regarding Blackdog in this news release, including whether either or both of the Acquisitions will be completed and the expected timing thereof, as well as the number of possible future drilling locations on Property A, the expected returns on investment in re-entries on Property B and the anticipated assessment of future productive capacity of the properties to be acquired, may constitute forward looking statements under applicable securities laws. Such forward-looking statements necessarily involve a number of substantial known and unknown risks including, without limitation, risks associated with the benefits to be derived from the Acquisitions, general risks associated with oil and gas exploration, development, production, marketing and transportation, loss of markets, volatility of commodity prices, imprecision of reserve estimates, environmental risks, competition from other producers, unexpected decline rates in wells, wells not performing as expected, delays resulting from or inability to obtain required regulatory approvals and ability to access sufficient capital from internal and external sources. As a consequence, actual results may differ materially from those anticipated in the forward-looking statements. Readers are cautioned that the foregoing list of factors is not exhaustive. Additional information on these and other factors that could affect Blackdog's operations and financial results are included in reports on file with Canadian securities regulatory authorities and may be accessed through the SEDAR website (www.sedar.com). The forward-looking statements or information contained in this news release are made as of the date hereof and Blackdog does not undertake any 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.

"Boepd" means barrels of oil equivalent per day. The term "barrels of oil equivalent" or "boe" may be misleading, particularly if used in isolation. A "boe" conversion ratio of 6 Mcf: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.

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Golar LNG Partners L.P.: Interim Results for the Period Ended June 30, 2013

Golar LNG Partners L.P.

oslo : GOLP01

HAMILTON, BERMUDA--(Marketwired - Aug 29, 2013) -

Highlights

* Golar LNG Partners LP ("Golar Partners" or the "Partnership") reports net income attributable to unit holders of $28.0 million and operating income of $44.4 million for the second quarter of 2013

* Generated distributable cash flow of $26.4 million for the second quarter of 2013

* Declared distribution of $0.515 per unit for the second quarter of 2013

* Golar Mazo and Methane Princess drydockings completed

* Refinanced Golar Winter and Golar Grand with a new bank loan facility $225 million term loan and a $50 million revolver

Subsequent events

* Golar Winter drydocking and modification works completed and vessel delivered to new location in Brazil

* Entered into an additional $100 million interest rate swaps

* Golar LNG Limited ("Golar" or "Golar LNG") secures two FSRU contracts that represent attractive near and medium term acquisition prospects

Financial Results Overview

Golar Partners reports net income attributable to unit holders of $28.0 million and operating income of $44.4 million for the second quarter of 2013 ("the second quarter"), as compared to net income attributable to unit holders of $30.3 million and operating income of $45.2 million for the first quarter of 2013 ("the first quarter") and net income attributable to unit holders of $30.2 million and operating income of $45.3 million for the second quarter of 2012(1).

Lower operating results for the second quarter of 2013 compared to the same period in 2012 is due largely to drydocking offhire time incurred in the second quarter of 2013, with none incurred in the comparable period, and increased drydocking cost amortization partly offset by the contribution of the NR Satu and Golar Maria in the second quarter. NR Satu was on hire throughout the second quarter of 2013 but was in the final stages of its FSRU conversion and commissioning during the earlier half of the second quarter of 2012, and, therefore, not generating revenues. Comparable results for 2012 do not reflect the contribution of Golar Maria as this vessel was not under the common control of Golar at the time of her acquisition by the Partnership in the first quarter of 2013.

Operating results for the second quarter are slightly lower than the first quarter primarily due to increased drydocking offhire days and higher drydock cost amortization, partly offset by a full quarter's contribution from Golar Maria, which was acquired on February 7, 2013.

Offhire time for the Golar Winter drydocking and modification work and the Methane Princess drydocking was approximately ten weeks in total. The Golar Mazo also completed its docking during the quarter without incurring offhire due to a drydocking allowance in its time charter. Partly mitigating the impact of the above dockings has been the biennial revision of the Golar Spirit and Golar Winter time charter rates resulting in an increase to hire rates during the quarter. The second quarter drew to a close an intense program of drydockings, the next scheduled drydockings are for Golar Freeze and Golar Grand which are not due until 2015. All other vessels operated well throughout the quarter with overall utilization at 100 per cent.

Following completion of the agreed modification work to Golar Winter and her redelivery to charterers, Golar Partners will receive approximately $24 million in additional revenue spread evenly over the remaining eleven years of the contract. This uplift is before the biennial rate revisions provided for in the charter.

Net interest expenses increased to $11.7 million for the second quarter of 2013 compared to $10.1 million for the first quarter. This is largely due to additional Indonesian witholding tax allocated to interest expense rather than corporation tax. As with the other Indonesian taxes incurred in connection with the vessel concerned, this tax is effectively rechargeable to the charterer.

Other financial items for the second quarter of 2013 recorded a small loss of $0.1 million compared with a gain of $1.1 million in the first quarter. Mark-to- market valuation gains on interest rate swaps were higher by approximately $2.5 million in the second quarter of 2013 compared to the first quarter but this was offset by the write off of deferred financing fees associated with the refinancing of the Golar Winter and Golar Grand leases.

The Partnership's Distributable Cash Flow(2) for the second quarter of 2013 was $26.4 million as compared to $27.6 million in the first quarter.

On July 25, 2013, Golar Partners declared a distribution for the second quarter of 2013 of $0.515 per unit which was paid on August 14, 2013.

Financing and Liquidity

As of June 30, 2013 the Partnership had cash and cash equivalents of $61.1 million and undrawn revolving credit facilities of $70 million. Total debt and capital lease obligations net of restricted cash was $1.0 billion as of June 30, 2013.

Based on the above debt amount and annualized(3) second quarter 2013 adjusted EBITDA(4 )Golar Partners has a debt to adjusted EBITDA multiple of 4.1 times.

In June 2013, the Partnership refinanced the Golar Winter and Golar Grand leases with a new 5 year $275 million loan facility. The facility is split into two tranches, a $225 million term loan and a further $50 million revolver, which remains undrawn as of June 30, 2013. The loan bears interest at LIBOR plus a margin and is repayable in quarterly instalments of $5 million with a final balloon payment of $130 million payable in July 2018.

As of June 30, 2013, Golar Partners had interest rate swaps with a notional outstanding value of approximately $906.5 million (including swaps of notional amount of $227.2 million in connection with the Partnership's bonds) representing approximately 90% of total debt and capital lease obligations, net of restricted cash. The average fixed interest rate of swaps related to bank debt and capital lease obligations is approximately 2.4% as at June 30, 2013. Subsequent to the quarter end the Partnership entered into a further $100 million seven year swap at a fixed rate of 2.16%. As of June 30, 2013 the Partnership had outstanding bank debt of $778 million with average margins, in addition to LIBOR or fixed swap rates, of approximately 2.3%. In addition, the Partnership has bonds of $214 million with a fixed rate of 6.485%.

Outlook

The announcement by Golar LNG of the contracting of two FSRU vessels provides Golar Partners its first two potential acquisitions from Golar LNG's fleet of 13 newbuildings.

The first contract is for the FSRU Igloo, which delivers in the fourth quarter of 2013, and is contracted to Kuwait National Petroleum Company ("KNPC") for an initial period of 5 years. The contract comprises the provision of portside FSRU services for an anticipated nine months of the year together with a three month window where the vessel is free to pursue spot carrier and other short term business opportunities. Winter scheduling of the three month stand-down period together with favourable positioning mean that the vessel should have realistic trading prospects. The contract is set to commence in March 2014 and has a total contract value of approximately USD$213 million covering both capital and operating elements over five years.

The second contract is with the Government of the Hashemite Kingdom of Jordan, represented by the Ministry of Energy and Mineral Resources ("the Government"). The FSRU Golar Eskimo will be moored at a purpose built structure that is to be constructed by the Aqaba Development Corporation off the Red Sea port of Aqaba. The FSRU will connect to the Jordan Gas Transmission Pipeline that delivers natural gas to power plants throughout the Kingdom. Earnings under the ten year contract are due to commence during the first quarter of 2015. Annual EBITDA contribution for the first five years of the contract will be approximately $46 million and approximately $43 million per year for the second five year term. The Government has the option to terminate the time charter after year five, subject to payment of an early termination fee.

With the recent contract announcements by Golar LNG and its remaining newbuild fleet of 11 as yet uncontracted vessels, the Board is confident that Golar Partners can continue to strongly grow its earnings and distributions over the longer term.

With the recent drydockings now completed the Board expects a significant improvement in operating results in the third quarter of 2013 with no drydocking offhire and high operational uptime expected. This will be enhanced by increased charter rates for the Golar Winter and Golar Spirit which were escalated according to the contract during the second quarter and the rate increase on the Golar Winter as a result of the modification work which is expected to take effect during the third quarter. Based on current operational performance of the vessels, the Partnership expects operating income in excess of $50 million in the third quarter.

With the growth opportunities outlined above, the Board remains very excited about the prospects of Golar Partners.

August 29, 2013

Golar LNG Partners L.P.

Hamilton, Bermuda.

Questions should be directed to:

C/o Golar Management Ltd - +44 207 063 7900

Brian Tienzo or Graham Robjohns

(1)Following the acquisition of the Golar Grand and NR Satu from Golar, the comparative results for the second quarter ended 2012 assume that the Golar Grand and NR Satu were wholly owned by the Partnership for the entire period that the vessels have been under the common control of Golar.

(2)Distributable cash flow is a non-GAAP financial measure used by investors to measure the performance of master limited partnerships. Please see Appendix A for a reconciliation to the most directly comparable GAAP financial measure.

(3)Annualized means the figure for the quarter multiplied by 4.

(4)Adjusted EBITDA: Earnings before interest, other financial items, taxes, non- controlling interest, depreciation and amortization. Adjusted EBITDA is a non- GAAP financial measure used by investors to measure our performance. Please see Appendix A for a reconciliation to the most directly comparable GAAP financial measure.

This information is subject of the disclosure requirements pursuant to section 5-12 of the Norwegian Securities Trading Act.

Golar Partners Q2 2013 Results: http://hugin.info/147317/R/1725799/575627.pdf

This announcement is distributed by Thomson Reuters on behalf of Thomson Reuters clients. The owner of this announcement warrants that:

(i) the releases contained herein are protected by copyright and other applicable laws; and

(ii) they are solely responsible for the content, accuracy and originality of the information contained therein.

Source: Golar LNG Partners L.P. via Thomson Reuters ONE

[HUG#1725799]

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