ROGTEC Magazine - Russian Oil & Gas Technologies - News, Reviews & Articles

ROGTEC Magazine - Russian Oil & Gas Technologies - News, Reviews & Articles

Caspian Oil and Gas: December Activity and Q1 Plans

Tuesday, January 31st, 2012

Perth-based exploration company Caspian Oil & Gas Limited is pleased to report its activities for the December 2011 Quarter.


- West Mailisu #2 produced a minor amount of oil (~20bbls) on test, indicating a tight and/or damaged reservoir
- Recorded 20km of 2D seismic over four leads in the East Mailisu and Charvak licences in November 2011
- Appointment of Mr Avraham Ben-Natan as a Non-Executive Director of the Company

March Quarter Plans

- Undertake workover of Mailisu III #6 to remove stuck perforation guns and production test the well
- Finalise interpretation of the 2011 East Mailisu and Charvak seismic acquisition
- Promote farm-out of Kyrgyz projects, subject to licence renewals
- Sale of Romanian oil interest

Kyrgyz Republic Projects


Caspian Oil & Gas, through its subsidiaries, holds six exploration licences and two production licences in the Fergana Basin, giving it a significant exploration position in the Kyrgyz Republic in Central Asia.


The West Mailisu prospect in the Kyrgyz Republic lies adjacent to the Mailisu IV oil field in the Kyrgyz Republic. The West Mailisu #2 well, which Caspian spudded in June 2011, was pump tested in December. Some 10m³ of completion fluid and 3.2 m³ (~20bbls) of oil was recovered before the pump ran dry. Subsequent measurement of the fluid level in the hole confirmed that there was little further influx into the wellbore from the formation, indicating that the formation is either tight and/or damaged. When drilling Well #2, Bed III was encountered high to prognosis, while still using heavy mud designed to drill the top section of the well. This heavy mud could be expected to cause severe reservoir damage. The commercial potential of the reservoir can thus only be established by sidetracking, radial drilling or fracture stimulating (“fraccing”) to test beyond the potentially damaged zone. Given the cost of mobilising the required specialised equipment, the Company is assessing its options.

Work activity is now focussed on the completion and testing the previously drilled Mailisu III #6 well. This 1,501-metre well intercepted oil within the carbonates of beds V and VII. Drilled in November 2009, it has not been tested to date due to stuck perforation guns and restrictions on acid sales throughout 2010. An attempt will be made to remove the stuck perforation guns using a recently acquired fishing tool to enable the pump and tubing to be set at the optimum level. Well #6 will then be pump tested before attempting an acid treatment.

Caspian is still waiting for the renewal of its exploration licences, which is considered an essential prerequisite to farming out the Kyrgyz acreage. A change of Government following the 30 October presidential elections and restructuring of the Mines Ministry to the Agency of Geology and Subsoil Usage have delayed consideration of Caspian’s request.


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Integra Group: 2012 Order Book Hits $510m USD, Up 21%

Monday, January 30th, 2012

Integra Group announces its current order book status for 2012.

As of January 30, 2012, the total order book, which includes the value of business to be delivered in 2012 contracted and won in tenders, was US$ 509.3 million (RR 15.9 billion). Of this amount, estimated value of signed contracts was US$ 190.1 million (RR 6.0 billion). Integra Group is in an active stage of contracting for 2012 which implies that current order book is not complete and does not yet provide an accurate indication of expected revenues in 2012.

Current 2012 order book (contracts signed and tenders won) is 21% higher in Ruble terms compared to 2011 order book reported on January 17, 2011 (adjusted for historic order book of discontinued businesses).


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Ru-No Barents Project, Russian – Norwegian Oil and Gas Industry Cooperation in the High North, is Launched

Monday, January 30th, 2012

During the 10th annual Russian-Norwegian oil and gas conference, Mr Ole T. Horpestad, Special Advisor, Ministry of Foreign Affairs, announced that the Ru-No Barents project (Russian – Norwegian oil and gas industry cooperation in the High North) has recieved 6 million NOK over three years as Governmental financial support and cooperation.

The project start-up will be February 1st. Ministry of Petroleum and Energy, The Barents Secretariat, North Energy, ConocoPhillips, Shell, GDF Suez, Norwegian Association of oil and gas Industry, Federation of Norwegian Industries, FMC Technologies, University of Nordland/High North Center for Business and Governance, Petroarctic, Tschudi Shipping, Gazprom, Shtokman Develoment AG, Sozvezdye, Union of oil & gas industrialists of Russia and Murmanshelf have already committed support to the project.

The main objective of the project is, through industry cooperation and knowledge of Arctic technology needs, to contribute to the growth of the Russian and Norwegian based industry participation in the future petroleum endaevours in the High North.

The project will:

1) Assess common technology challenges Russia and Norway face in the development of the High North.

2) Analyze existing technologies, methods and best practice Russian and Norwegian industry can offer for the High North today.

3) Based on the above: Visualize the need for innovation and technology development the industry in our two countries needs to overcome.

4) Promote stronger industrial links between our two countries.

The five predefined main focus areas are:

1) Drilling, well operations and equipment
2) Pipelines and subsea installations
3) Floating and fixed installations
4) Logistics and transport
5) Environmental protection, monitoring systems and oil spill contingency

More information about the project? Please contact:

Project Director Barents, Thor Christian Andvik: / + 47 90 95 52 40


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Tethys Petroleum announces inauguration of Aral Oil Terminal

Monday, January 30th, 2012

Tethys Petroleum Limited, today announced the official inauguration of its Aral Oil Terminal (“AOT”) ‐ a new oil storage and rail loading facility for oil shipments from the Company’s Doris oilfield into the Kazakh rail system.

The AOT is located approximately 230 km from the Doris oil field, significantly reducing the distance oil is currently trucked by road from the field. The opening of AOT will allow the Company to initially double production to approximately 4,000 barrels of oil per day (“bopd”) due to a halving of the road trucking distance. Furthermore, the current rail loading point at Emba experiences bottlenecks due to overuse by many different companies; the AOT will be dedicated to Tethys oil sales. The opening of the AOT will thus reduce transportation costs significantly and will result in an increased realised oil price. The recent acquisition of additional road trucks means that 240 are
now in daily operation.

To date, over 13,000 bopd have been tested from exploration and appraisal wells in and around the Doris accumulation. This is the first stage of the AOT, and it is planned to expand the facility to 12,000 bopd in the upcoming year. In addition to a rail loading facility the terminal will provide a closer offloading point for refined oil products,
equipment and materials required on the Doris exploration and appraisal programme which in turn will result in significant cost savings to the Company.

The AOT is owned and operated jointly through a 50:50 joint venture by Tethys and its Kazakh oil trading partner’s company, Olisol Investment Ltd. At the inauguration ceremony both Tethys and its partner were present, together with local and regional officials. First commercial shipments through the AOT are expected in February of this


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Duraband NC Hardbanding for Harsh Drilling Conditions

Thursday, January 26th, 2012

Hardbanding Solutions, a business unit of Postle Industries, offers Duraband®NC for HPHT, Sour Gas, Highly Deviated and Geothermal Wells. Drilling these types of wells can be very hard on hardbanding and drill pipe tool joints. In addition, casing can show excessive wear. In these types of wells, typical hardbanding products that contain cracks frequently result in spalling and chipping caused by unwanted materials getting into and under the crack. This requires premature removal of the drill pipe for repair and re-application of the hardband, adding extra costs to any drilling operation.

Non-Cracking Duraband®NC is the ideal solution. It is the first product ever developed offering maximum protection that is applied 100% crack-free. Without cracks, high temperatures, steam, abrasives, and drilling fluids cannot penetrate into and underneath the hardband. Furthermore, it offers superior wear resistance and longer downhole life, thereby reducing drilling costs.

Furthermore, Duraband® NC can be applied over itself without any special preparation. The cost of re-application is substantially reduced since it does not have to be removed. With other hardbanding products, the cost of re-application can be 3 or 4 times higher since they have to be removed before re-application.

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Max Petroleum: SAGW-3 Bit Spins

Wednesday, January 25th, 2012

Max Petroleum Plc, an oil and gas exploration and production company focused on Kazakhstan, is pleased to announce that it has commenced drilling the SAGW-3 appraisal well on the Sagiz West Field in Block E. Total depth of the well will be approximately 1,400 metres, targeting Triassic reservoirs.


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Gazpromneft-Nefteservis sells Servisnaya Burovaya Kompaniya and KRS-Servis

Tuesday, January 24th, 2012

At the end of December 2011, Gazpromneft-Nefteservis completed the sale of two of the main production unit’s companies – Servisnaya Burovaya Kompaniya (SBK) and KRS-Servis (KRS). Both assets were bought by OJSC RU-Energy Group . The deals were approved by the Russian Federal Anti-monopoly Service.

SBK and KRS will retain their long-term contracts with the Gazprom Neft group companies, with a guaranteed amount of work by the end of 2013. The agreements also provide for the continuation of the new owner’s obligations to comply with the conditions of collective employment agreements adopted by Servisnaya Burovaya Kompaniya and KRS-Servis.

The decision to spin off the oilfield service companies from Gazprom Neft was made by the Board of Directors in March 2010, while the programme to withdraw from the oil field services business ran until the end of 2011. Muravlenkovskaya Transportnaya Kompaniya was sold at the end of January 2011, SpetsTransServis, Noyabrskaya Tsentralnaya Trubnaya Baza and Servisnaya Transportnaya Kompaniya were sold in the summer, and YamalServisTsentr was sold in October. Moreover, in 2011 Gazpromneft-Nefteservis sold a controlling stake in its subsidiary Noyabrskneftespetsstroy. In November 2011, Gazprom Neft Board of Directors reviewed the interim results of the programme to exit from the company’s oilfield services business.

“The finalisation of the transactions for the sale of SBK and KRS completes the company’s programme to withdraw from the oil field services business, which has enabled Gazprom Neft to reduce costs and promote competition in the relevant markets”, said Alexander Dyukov, Chairman of Gazprom Neft’s Executive Board.


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Dragon Oil Trading Statement and Reserves Update

Monday, January 23rd, 2012

Dragon Oil plc, an international oil and gas exploration and production company, today issues the following trading statement, which includes an operational update, financial highlights for 2011 and the results of the latest reserves assessment. All information referred to in this update is unaudited and subject to further review. Dragon Oil expects to publish its 2011 full-year financial results on 21 February 2012.

Key operational highlights

· 30% increase in average daily production rate to approximately 61,500 barrels of oil per day (“bopd”) in 2011 compared to 47,200 bopd in 2010;

· 70,000 bopd target production rate reached in mid-December 2011 with the final 2011 exit rate higher at 71,751 bopd;

· Thirteen new development wells successfully put into production against an initial guidance of 11 wells; and

· Drilling from the Dzheitune (Lam) C platform commenced.

Key corporate highlights

· Year-end oil and condensate reserves increased by 41 million barrels to 658 (December 2010: 639) million barrels at year-end 2011; gas reserves and contingent gas resources remained at similar levels of c. 3 TCF;
· Farm-in agreement for an exploration asset in Tunisia with a 55% participating interest signed;

· Limited buyback programme concluded on 4 November 2011 with five million shares purchased at a weighted average price of GBP 4.84 per share; and

· Marketing route for full entitlement volumes secured until end-2012.

Key financial highlights

· Capital expenditure on infrastructure and drilling amounted to US$351 million for 2011 (2010: US$460 million); and

· Group’s cash balance (net of abandonment and decommissioning funds) as at 31 December 2011 was US$1,527 million (31 December 2010: US$1,163 million).

Dr Abdul Jaleel Al Khalifa, CEO, commented:

“2011 was an impressive year in terms of production and reserves growth: we succeeded in increasing gross field production by almost a third from the 2010 level thanks to an intensive drilling programme and strong results from the Dzheitune (Lam) West area. Encouraging results from the Dzheitune (Lam) West area have been meeting and at times surpassing our expectations since we entered this previously undrilled area in 2007 and have led to a significant upgrade of our oil and condensate 2P reserves. This year, we were able to achieve a 183% organic replacement of produced reserves, a remarkable achievement.

“As a result of strong oil prices and production growth, we have generated over US$1 billion in revenues, the highest annual earnings ever; this further strengthens our financial position as we continue our growth towards the production target of 100,000 bopd and actively pursue acquisition opportunities following the Tunisian farm-in of last year.”


Gross field production for 2011 averaged 61,500 bopd (2010: 47,200 bopd). The increase over the previous year is an impressive 30% as a result of an extensive drilling programme undertaken during the year. The initial plans of completing 11 wells during 2011 were upgraded to 13 wells allowing us to achieve production growth significantly above the initial guidance of 10-15%.

The entitlement production for 2011 was approximately 53% (2010: 61%) of the gross production. Entitlement barrels are finalised in arrears and are dependent on, amongst other factors, operating and development expenditure in the period and the realised crude oil price. The lower proportion of entitlement barrels in 2011 is primarily due to the higher realised crude oil price and lower development expenditure during the year.


Dragon Oil sold 11.4 million barrels of crude oil in 2011 (2010: 10.8 million barrels). The 6% increase in the volume sold over the previous year is mainly due to higher production. The increase in the volumes of crude oil sold was less than the production growth rate due to a combination of a lower entitlement rate in 2011 compared to 2010 and changes in the lifting and inventory positions.

In 2011, Dragon Oil exported approximately 99% (2010: approximately 60%) of its crude oil production through Baku, Azerbaijan with the balance sold to an independent third party.

The current marketing route via Baku, Azerbaijan has been extended until 31 December 2012 for the full entitlement production volume giving us comfort in being able to sell our share of the crude oil production this year. The terms of the contract remain FOB the Aladja Jetty primarily using the BP-operated BTC (Baku-Tbilisi-Ceyhan) pipeline. It is expected that for 2012 realised crude oil prices will be less favourable (10% to 13% discount to Brent) than the historic realised prices generated through that route in 2011.

The Group was in an underlift position of approximately 0.05 million barrels of crude oil at the end of 2011 (31 December 2010: overlift position of 0.2 million).


During 2011, Dragon Oil completed a 13-well drilling programme in the Dzheitune (Lam) field. The following table summarises the results of this drilling programme:

We originally targeted the completion of 11 wells during 2011; however, we were able to upgrade our plans to 13 wells thanks to the optimisation of the drilling programme. A faster drilling rate by the NIS rig allowed us to complete six wells versus up to five wells planned at the beginning of the year; while availability of additional slots on the Dzheitune (Lam) A platform gave us an opportunity to drill an extra well using the Iran Khazar rig.

In early January 2012, we reported successful completion and testing of a sidetrack of the Dzheitune (Lam) 13/140 well performed by Rig 40 and we put into production the Dzheitune Lam A/165 well, a strong start to the 2012 drilling programme.

The table below summarises the results from drilling in the Dzheitune (Lam) field reported since the beginning of the year:

The Iran Khazar and the NIS rigs are currently drilling the Dzheitune (Lam) C/167 and 28/166 wells, respectively, while Rig 40 is working over the Dzheitune (Lam) 13/144B well.

During 2011, Dragon Oil employed three drilling rigs for all or part of the year. The same rigs are expected to be used in 2012 for all or part of the year, along with an addition of the Super M2 jack-up rig, which is expected in 1H 2012, as well as another 2,000 horse-power platform-based rig, which is planned for mobilisation in 2H 2012.


Installation of the Dzheitune (Lam) C platform was completed on schedule and drilling commenced in early January 2012 with the Iran Khazar rig spudding the first well on this platform, Dzheitune (Lam) C/167.

In 2011, we carried out structural upgrades on four platforms adding four extra slots for drilling with a jack-up drilling rig on each of: the Dzheitune (Lam) platforms 21 and 22 and Dzhygalybeg (Zhdanov) platforms 21 and 60. This allows us to create additional capacity in our infrastructure from which we can benefit later should we need to adapt our drilling plans. Six slots were added on the Dzheitune (Lam) A platform allowing us to schedule the Iran Khazar rig for drilling from this platform in 2011.

The Dzheitune (Lam) Block-1 riser platform has been commissioned following the re-connection of the pipelines feeding into this gathering station from the old block. Block-1 will act as a gathering station and will help increase the throughput capacity of the Dzheitune (Lam) West area.

Completion of the Dzhygalybeg (Zhdanov) A and B platforms is anticipated in 3Q 2012 and 1H 2013, respectively. Each platform will have 16 slots and an accommodation facility; their design will allow the deployment of either a platform-based or a jack-up rig.

Completion of Block-4 riser platform and installation of the associated pipelines are expected in the second half of 2012. It will act as a gathering station for the production from new wellhead and production platforms in the Dzhygalybeg (Zhdanov) field.

Reserves and resources

Based on the results of the recent assessment by an independent energy consultant, the 2011 year-end oil and condensate 2P reserves were upgraded to 658 (31 December 2010: 639) million barrels. The gas 2P reserves decreased slightly to 1.5 (31 December 2010: 1.6) TCF corresponding to approximately 250 million barrels of oil equivalent dependent on the ongoing discussions with the government of Turkmenistan on a gas sales agreement

The oil and condensate contingent resources of 88 million barrels and the increase of approximately 41 million barrels in oil and condensate reserves are mainly due to an increase in reserves in the Dzheitune (Lam) West area. The Dzheitune (Lam) and Dzhygalybeg (Zhdanov) fields were discovered in the Cheleken Peninsula in Turkmenistan in the 1960s-70s. Since 2000, Dragon Oil managed to ramp up production ten-fold by introducing new drilling techniques and targeting previously undrilled areas, such as the Dzheitune (Lam) West in 2007. We have been drilling from the Dzheitune (Lam) 28 platform and have installed two new wellhead and production platforms, Dzheitune (Lam) B and C. Thanks to directional drilling certain wells drilled outside the proven hydrocarbon boundary in the Dzheitune (Lam) West area have shown a bigger area extension with a higher potential for the shallow reservoirs. These findings led to an increase in our oil and condensate reserves and resulted in a reserve replacement of 183% against the 2011 gross production.

The gas contingent resources remained at 1.4 (31 December 2010: 1.4) TCF. Necessary upgrades of and additions to offshore and onshore infrastructure are planned to allow the conversion of the contingent resources into reserves in the future.

No changes have been made to the estimates of recoverable oil from the Dzhygalybeg (Zhdanov) field, where we believe 15% of the total proved and probable recoverable reserves are contained and flow rates are expected to be lower than those seen in the Dzheitune (Lam) West area. We plan to start drilling in the Dzhygalybeg (Zhdanov) field later this year. This will enable us to understand better what the field is capable of producing.

Capital expenditure

Capital expenditure for 2011 was approximately US$351 million (2010: US$460 million). Of the total capital expenditure, approximately 47% (2010: 55%) was attributable to infrastructure with the balance spent on drilling. The infrastructure spend during the year included construction of the Dzheitune (Lam) C and Dzhygalybeg (Zhdanov) A platforms, work on Block 2, 4 and 1 gathering stations, additional slots on the Dzheitune (Lam) A platform, upgrade of certain existing platforms and construction of a crane vessel, as well as the geophysical and geotechnical investigation to evaluate locations for future platforms.

Realised prices

Dated Brent for the year averaged approximately US$111 per barrel, about 41% above 2010′s average of approximately US$79 per barrel. The average realised crude oil price during 2011 was approximately US$101/bbl (2010: US$72/bbl), at a 9% (2010: 9%) discount to Brent. In 2012, the level of discount is expected to range between 10% and 13% to Brent, less favourable than the historic discount rates achieved.

Total revenue for 2011 is expected to be approximately US$1.1 billion (2010: US$780.4 million) subject to final audit. The full-year audited results will be reported on 21 February 2012.

Gas Monetisation

The commissioning of the gas compressor station in Hazar, Turkmenistan has enabled the Group to reduce gas flaring – a fact that is important to us as a good corporate citizen and one of the largest independent hydrocarbon producers in Turkmenistan. We continue to discuss with the government of Turkmenistan a range of options for the monetisation of gas, including a long-term gas sales agreement, targeted towards export markets. We are also reviewing options for the condensate recovery.


On 10 October 2011, Dragon Oil announced that it had signed a farm-in agreement with a wholly owned subsidiary of Cooper Energy Limited through which Dragon Oil is to earn a 55% participating interest in the Bargou Exploration Permit, offshore Tunisia, subject to confirmation from the Government of Tunisia. Further, if the Joint Venture proceeds with a development phase, Dragon Oil will assume operatorship of the block.

In Iraq, Dragon Oil has been pre-qualified to participate in the fourth round of bidding (due to take place in 1H 2012).

Dragon Oil continues to screen and evaluate targets that fit our criteria within Africa, Central Asia, the Middle East and selectively south-east Asia in order to create a diversified balanced portfolio of assets for the Group.

Share Buyback Programme

In 2011, Dragon Oil launched a limited share buyback programme of up to five million shares in the Company. The buy-back programme commenced on 26 September 2011 and concluded on 4 November 2011. The sole objective and purpose of the programme was to meet all relevant obligations arising from the Company’s various share schemes.

As of 4 November 2011, 100% of the targeted number of shares was purchased at a weighted average price of GBP 4.84 per share.


For 2012, our target is to achieve a 15% gross production increase on the basis of 13-15 wells expected to be put into production and a number of workovers. The first well, the Dzheitune (Lam) A/165, and a sidetrack of the Dzheitune (Lam) 13/140 have already been completed, leaving the Iran Khazar and NIS rigs, Rig 40, Super M2 jack-up rig and a platform-based rig that is currently being sourced to complete the remainder of the wells planned for 2012.

Over the 2012-15 period, we expect to maintain an average production growth of 10% to 15% per annum, taking our gross field production to a level of 100,000 bopd in 2015 with the aim of maintaining this plateau for a minimum period of five years. Delivery of the production targets, including the attainment of the plateau production level is supported by a development plan that envisages deployment of up to three jack-up rigs, additional platform-based rigs, construction of new platforms and execution of a range of key infrastructure projects.

The Group expects to report its 2011 full-year financial results on 21 February 2012.


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Novatek and Gazprom Discuss Possible Joint LNG Projects

Monday, January 23rd, 2012

OAO NOVATEK announced today that the Company’s Chairman of the Management Board, Leonid Mikhelson, and the Chairman of the Management Board of OAO Gazprom, Aleksey Miller, held a working meeting which was also attended by the Chairman of the Management Board of Gazprombank (OAO), Andrey Akimov.

The purpose of the meeting was the discussion of possible joint projects between NOVATEK and OAO Gazprom to increase LNG production capacity near the port of Sabetta, located on the Yamal peninsula, through the development of new fields in the northern part of the peninsula, as well as considering the possibility of a joint development strategy for the hydrocarbon resources of the Gydan peninsula to offset declining production in the Nadym-Pur-Taz region.


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Roxi Petroleum: NW Konys Commences Pilot Production

Monday, January 23rd, 2012

Roxi, the Central Asian oil and gas company with a focus on Kazakhstan, is pleased to announce the commencement of pilot production from the NW Konys field in the Galaz Contract Area, in the Kyzylorda Oblast Western Kazakhstan, on 19 January 2012.

The Company successfully drilled six new wells on the NW Konys field in 2008/9 and re-entered one old well drilled in the 1990s. The wells were tested and shut-in pending application and receipt of final regulatory approvals, which were received in December 2011.

Well NK-6 re-commenced production from NW Konys on 19 January 2012, achieving a rate of approximately 225 barrels of oil per day (“bopd”). The oil is a saturated, low sulphur crude, with a density of 37-39o API, and wax content varying between 12% and 29%. Production is currently being transported by road to neighboring operating company KuatAmlonMunai (KAM) for sale on the domestic market.

The Company, together with its farm-in partner LG International, now plans to re-commence production from another of its previously drilled wells, well NK-4 as well as testing multiple intervals in well NK-9, before moving to test well NK-10, both of which were recently successfully drilled to a depth of 1500 metres.

David Wilkes, CEO commented

“Pilot production at NW Konys represents a significant milestone for Roxi, and is the first of three fields we plan to bring into production in 2012.

We now look forward to enhancing production levels from the NW Konys field, starting first with well NK-4 and thereafter from further appraisal wells as they are completed throughout 2012.

I would like to thank our partners LG International, who have successfully navigated this asset through to production, since they became operators of Galaz in 2010.”


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