Located approximately 46 miles (75 km) off the coast of Pointe-Noire in water depths ranging from 2,400 to 4,000 feet (750 to 1,200 meters), Moho Bilondo Phase 1b is part of the Moho Nord joint development project, the largest-ever oil and gas project undertaken in the Republic of Congo. The Moho Bilondo Phase 1b project includes 11 wells tied back to an existing floating production unit and is expected to produce a total of 40,000 barrels of oil per day.

“First oil from the Moho Bilondo Phase 1b development is the latest successful start-up in our diverse portfolio of deepwater projects, which we expect to generate value for years to come,” said Jay Johnson, executive vice president Upstream, Chevron Corporation.

“The successful development of Phase 1b demonstrates our ongoing commitment to the Republic of Congo and is a testament to industry and government cooperation,” said Ali Moshiri, president of Chevron Africa and Latin America Exploration and Production Company. “The project integrates the unique skills and expertise of multiple partners to deliver challenging projects and new energy production.”

The Phase 1b development targeted reserves in the southern portion of the Moho Bilondo permit area. The Moho Nord subsea development, which will be the second phase of the Moho Nord joint development project, is in the northern part of the area.

The Moho Nord development project involves a tension-leg platform, a floating production unit with a processing capacity of 100,000 barrels of oil per day, and a 50-mile (80-kilometer) pipeline to the onshore Djeno Terminal.

Chevron Overseas (Congo) Limited has a 31.5 percent working interest in the Moho Bilondo permit area, along with Total E&P Congo (53.5 percent working interest and operator) and the national oil company, Société Nationale des Pétroles du Congo (15 percent working interest).

• Chevron Confirms First Production from the Moho Bilondo Phase 1b Development Offshore the Republic of Congo

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For the Donges project, Axens has proposed an optimized process scheme specifically adapted to the existing refinery environment, and incorporating Total’s requirements in terms of energy efficiency and operational flexibility.

VGO HDS technology is part of Axens’ extensive portfolio in the field of middle distillates, VGO hydrotreating and hydroconversion, with more than 220 units licensed in the world totalizing close to 10 million BPD capacity.

Axens supplies VGO HDS technology license, basic engineering, proprietary catalysts and equipment as well as related services: training, unit start-up and follow-up.

• Axens’ VGO HDS technology selected by Total for its Donges Refinery, France

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“The Dalia FPSO came on stream nearly nine years ago and with the addition of Phase 1A will still produce around 200,000 b/d. It is the latest milestone in the success story of Block 17, Total’s most prolific license with cumulative production reaching two billion barrels in May 2015,” explained Arnaud Breuillac, President Exploration & Production. “Dalia Phase 1A demonstrates Total’s commitment to maximizing value through the optimal use of existing facilities. These types of profitable satellite tie-back developments play an important role in maintaining production levels and generating additional free cash flow for the Group.”

The Dalia Phase 1A project involves the drilling of seven infill wells tied back to the Dalia Floating Production Storage and Offloading (FPSO) unit.

Total Exploration & Production in Angola

Total celebrated its 60th anniversary in Angola in 2013. In 2014, the Group’s equity production reached 200,000 barrels of oil equivalent per day (boe/d), coming essentially from Blocks 17, 0 and 14. In early 2015, Total’s operated production exceeded 700,000 boe/d, making it the country’s leading oil operator.

Total operates Block 17 with a 40% interest alongside Statoil (23.33%), Esso Exploration Angola Block 17 Ltd (20%) and BP Exploration Angola Ltd (16.67%). Sonangol is the concessionaire of the license. The Group operates four FPSO units on the major production zones of the block: Girassol, Dalia, Pazflor and CLOV.

Total also operates with a 30% interest the ultra deep offshore Kaombo development located on Block 32. A final investment decision was made in April 2014 to develop Kaombo’s estimated reserves of 650 Mb via two converted FPSOs with a total production capacity of 230,000 b/d.

• Angola: Total starts up production from Dalia Phase 1A on deep offshore Block

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The operator Total has a 30% share on Block 32. The other partners are Sonangol Pesquisa & Produção (30%), Sonangol Sinopec International Limited (20%), Esso (15%) and Galp (5%).

Scope of supply is for two identical produced water treatment systems that will each process 170,000 BPD produced water. The systems comprise Alderley’s AP20 de-oiling hydrocyclones, Alderley’s AP25 de-sanding hydrocyclones, Compact Flotation Unit (CFU), a sand wash vessel and an additional oily water reject treatment stage.

The complete produced water treatment system is designed to meet the oil-in-water discharge levels of <20mg/l and 0.5% by weight, oil on sand.

Tony Mansfield, Managing Director, Alderley Process Technologies, comments, “Alderley have delivered a number of produced water treatment packages specifically designed for an FPSO environment. We recognise the strategic importance of this flagship project for Total and its partners and we are proud to be able to leverage on our extensive experience to offer the best technologies for their produced water requirements.”

The systems are being designed and engineered by Alderley Process Technologies team in the UK and manufacturing will take place in the Middle and Far East.

Alderley Process Technologies is part of the Alderley Group and provides the full range of services for engineering, supply and operation of produced water treatment solutions globally.

• Awarded FPSO Produced Water Treatment Packages

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Previous guidance for first LNG was in the second half of this year.

“The progress at GLNG over the past year has been excellent. This announcement highlights our confidence of delivering this transformational project on time and within the US$18.5 billion budget,” Santos Managing Director and Chief Executive Officer David Knox said.

“The project has continued to go from strength to strength and we have made significant progress on the ground in both 2014 and in the first quarter of this year.”

“The delivery of GLNG will consolidate our strategic LNG portfolio and further position us as a key player in the growing Asian gas market.”

Santos Vice President Downstream GLNG Rod Duke acknowledged the hard work and dedication of the project team in delivering the key milestones to date.

“It has been a fantastic year of progress at GLNG with recent milestones including the introduction of first gas into the LNG plant and the successful firing of the first two gas turbine generators,” Mr Duke said.

GLNG 2014-2015 SNAPSHOT

• Completed construction of all major gas field processing facilities.
• Completed its 420-kilometre pipeline, including a 4.3km undersea pipeline tunnel.
• Installed all 111 modules that make up its two LNG processing trains.
• Hydrotested both of its LNG storage tanks.
• Built its LNG loading jetty.
• Introduction of first gas into the plant and lighting of the flare.
• Successful firing of the first two gas turbine generators.

• Santos narrows GLNG start date

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Three of Total’s five refineries in France — Gonfreville in Normandy, Grandpuits in the Paris region and Feyzin near Lyon — demonstrated their ability to withstand the deteriorating economic environment in 2013 and 2014 and generate ongoing income streams. The other two, Donges and La Mède, are struggling and are structurally loss-making. To address the situation, Total has presented a comprehensive plan to improve both refineries’ performances and secure their long-term future:

• An investment of €200 million to transform the La Mède refinery and in particular create France’s first biorefinery, which will be one of the biggest in Europe, to meet growing demand for biofuels. Crude oil processing will be halted at end-2016.
• An investment of €400 million to upgrade the Donges refinery to capture profitable new markets with low-sulfur fuels that meet the evolutions of European Union specifications.

“There are three possible responses to the crisis in the European refining industry. The first is to throw in the towel. The second is to do nothing and perish. The third is to innovate and adapt to meet shifting demand trends. The central focus of Total’s plan for our French refining business is to realign our operations and products to changing markets. The plan that we are presenting today offers sustainable solutions for the Donges and La Mède refineries. It gives both facilities a future and strengthens Total’s refining base in France,” commented Patrick Pouyanné, Chief Executive Officer of Total. “As was the case for the project to secure the future of the Carling plant in eastern France, the master words for the plan’s deployment are: anticipation and consensus. Total will implement this industrial transformation without layoffs or imposed geographical transfers for non-exempt employees.”

Responding to Industry and Market Trends

European demand for petroleum products has declined 15% since 2008, shrinking outlets for the continent’s refining industry. This underlying trend stems from pursuit of energy efficiency and improved vehicle fuel economy as part of the European Union's commitment to reducing its carbon footprint.

The European market is steadily contracting, a situation aggravated by the shale oil and gas revolution in the United States, which gives the U.S. refining industry an advantage, and competition from refineries in Asia and the Middle East. These two trends shut European refineries out of some of their domestic and export markets and have exacerbated excess refining capacity in Europe.

As Europe’s leading refiner, Total is therefore continuing to adjust its production base in France, following the shutdown of the Flandres refinery (2010), the upgrade the Normandy refining & petrochemicals platform (2012) with an investment close to €1 billion and the implementation of the project to secure Carling's future (2015).

Including the adaptation plan for the Lindsey Oil Refinery in the United Kingdom announced earlier this year, Total will have successfully adapted by 2017 its European refining base to the market and cut its refining and petrochemical capacity by 20% in Europe in 2017, as announced in 2012.

• Total’s French Refining Roadmap: Upgrade Donges And Transform La Mède

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“The sale of these non-operated onshore blocks in Nigeria is yet another example of our strategy of dynamic portfolio management, achieved at attractive valuations,” said Patrick de La Chevardière, Chief Financial Officer at Total. “These transactions also reduce our exposure to non-operated blocks onshore Nigeria, and allow us to focus on our core, operated developments, such as the Egina project.”

Total holds a 10% stake in several onshore blocks in Nigeria via the Shell Petroleum Development Company (SPDC) Joint Venture alongside the Nigerian National Petroleum Corporation (55%), SPDC (30%, operator) and Nigerian Agip Oil Company Limited (5%). Since 2010, Total has divested its interests in eleven onshore blocks to Nigerian companies, in line with the Federal Government of Nigeria’s aim of developing Nigerian companies in the sector.

Total Exploration & Production in Nigeria

In 2012, Total celebrated fifty years of its presence in Nigeria. The Group’s production in Nigeria was 257,000 barrels of oil equivalent per day (boe/d) in 2014.

Deep offshore developments are one of Total’s main growth avenues in Nigeria, where the Group operates the Akpo field in OML 130 and launched the development of the Egina field in the same lease in 2013.

Offshore production also comes from OMLs 99, 100 and 102, which are operated by the Group as part of a joint-venture with NNPC. The main fields in these leases are Amenam-Kpono, Edikan and Ofon. On Ofon, Total completed the flare-out in January 2015 which will allow for the gradual increase of production towards the 90,000 boe/d production target.

Total’s onshore production comes from OML 58, which it also operates as part of its joint-venture with NNPC. A project is underway to increase the lease’s natural gas and condensate production capacity to supply the domestic market.

In addition, Total has significant equity production in Nigeria from its interests in non-operated ventures, particularly the SPDC-operated joint venture (10%) and the Bonga field (12.5%). Total also has a 15% interest in Nigeria LNG, which operates six LNG liquefaction trains on Bonny Island with a capacity of 21.9 million metric tons per year.

Total deploys an active policy to create in-country value in Nigeria - the Group is helping Nigerian contractors to build deep offshore expertise, especially in the Niger Delta, a region that is home to more than half of Total’s Nigerian employees and most of its operations in the country. Local content accounted 90% for the onshore OML 58 projects, and is likely to reach 75% for the deep offshore Egina development.

• Nigeria: Total Completes $1 Billion Of Onshore Divestments

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The Glenlivet specific scope includes:

• fabrication and installation of 12" production pipeline and 6" MEG(1) pipeline complete with a 2" piggy backed service line,
• supply and installation of steel tube umbilical, manufactured at Technip Umbilicals facility in Newcastle, UK,
• supply and installation of flexible tails from Flexi France, the Group’s manufacturing plant in Le Trait, France,
• fabrication and installation of pipeline end manifold, flowline end terminations, flexible tails and rigid well tie-in spools, as well as the installation of CPI(2) templates and manifolds,
• rock dumping and pre-commissioning.

The Group will leverage its unique vertical position in the subsea business:

• Technip’s operating center in Oslo, Norway, will execute the project in full synergy with the previously awarded Edradour project.
• Vessels from the Group fleet will perform the installation in the summer seasons of 2016 and 2017.
• The pipelines will be fabricated at Technip’s spool base at Evanton, UK, and installed by Technip’s vessel Deep Energy.
• Umbilicals will be manufactured at the new Technip umbilicals facility in Newcastle, UK.

Knut Boe, President North Sea Canada, stated: “It is very good to see the benefits of the synergies between these two projects being realized by Total’s award of this extra scope to Technip.”

• Technip awarded subsea contract for the Glenlivet project, West of Shetlands, UK

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“With the start-up of the West Franklin Phase 2 project, Total consolidates the production capacity of its operated Elgin/Franklin hub. The hub holds significant reserves as well as promising exploration opportunities”, outlined Michael Borrell, Total’s Senior Vice President Exploration & Production, Europe and Central Asia.

West Franklin Phase 2 will develop reserves of 85 million barrels of oil equivalent. The project includes the drilling of three new production wells and the installation of two new platforms, the West Franklin wellhead platform and the Elgin B platform which will be also used to drill new wells on Elgin.

Located approximately 240 km east of Aberdeen, West Franklin was discovered by Total in 2003 and Phase 1 production started in 2007 with two wells drilled from the Franklin platform.

Total operates Elgin/Franklin, including West Franklin, with a 46.2% interest alongside co-venturers Eni (21.9%), BG (14.1%), E.ON (5.2%), ExxonMobil (4.3%), Chevron (3.9%), Summit (2.2%) and Dyas (2.2%).

Total Exploration & Production in the United Kingdom

Total has been present in the United Kingdom since 1962. The Group is one of the country’s leading oil and gas operators, with equity production of 105,000 boe/d in 2013.

More than 90% of Total’s production in the UK comes from several operated fields located offshore in two major zones: the Alwyn/Dunbar area in the Northern North Sea and the Elgin/Franklin area in the Central Graben.

In 2015, Total will commence production from its new third hub located in the West of Shetland area, with the start-up of the Laggan-Tormore project.

• UK: West Franklin Phase 2 brought on stream in the North Sea

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“The flare-out of the Ofon field illustrates our commitment to developing oil and gas resources around our existing hubs in Nigeria. This important milestone of the Phase 2 of the Ofon project was achieved in a context of high levels of local content,” commented Guy Maurice, Senior Vice President Africa at Total Exploration & Production. “The flare-out on Ofon is also significant for Total’s environmental targets, representing a 10% reduction in the Group’s E&P flaring. This achievement is a clear demonstration of Total’s commitment to the Global Gas Flaring Reduction Partnership promoted by the World Bank.”

The Ofon field is located 65 kilometers from Nigerian shores in water depths of 40 meters. The field initially commenced production in 1997 and is currently producing about 25,000 barrels of oil equivalent per day (boe/d). This flare-out milestone will allow for the gradual increase of production towards the 90,000 boe/d production target through monetization of around 100 million cubic feet of gas per day, followed later in 2015 by the drilling of additional wells. The execution of the project also involved significant local content, including the first living quarters platform to be fabricated in Nigeria.

Total E&P Nigeria operates OML 102 with a 40% interest, alongside the Nigerian National Petroleum Corporation (60%).

• Nigeria: Total achieves flare-out on its operated Ofon field

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“Eldfisk came on stream in 1979 and the field still has significant reserves. The Eldfisk II project should extend the lifespan of Eldfisk for some 40 further years,” said Michael Borrell, Total’s Senior Vice President Exploration & Production, Europe and Central Asia. “Following the start-up of Ekofisk South end of 2013, the start-up of Eldfisk II demonstrates once again the potential for value creation in mature fields such as the Greater Ekofisk Area.”

Located approximately 300 kilometers off the Norwegian coast, the Eldfisk II project consists of a new platform (Eldfisk 2/7S), a substantial upgrade of the existing Eldfisk facilities and the drilling of 40 new production and injection wells.

The PL 018 partners are Total (39.9%), ConocoPhillips (35.1%, operator), Eni (12.4%), Statoil (7.6%) and Petoro (5.0%).

• Norway: Eldfisk II brought on stream in the North Sea

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But for Total, Egina also emphasizes Nigerian content. Several thousand local jobs will be created and extensive local infrastructure (mainly yards) will be upgraded or built, contributing to Nigeria's sustainable development. This win-win situation should enable Total to productively pursue a partnership that began more than 50 years ago.

• Drilling Program Begins on the Deepwater Egina Field in Nigeria

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The order comprises compact heat exchangers for various duties, such as cooling, heating and condensation, in the processing of crude oil on-board the FPSOs (Floating Production Storage and Offloading vessels).

“This is yet another order related to the oil and gas industry, this time to the offshore sector. It proves our products’ performance and reliability in these heavy duties,” says Lars Renström, President and CEO of the Alfa Laval Group.

• Alfa Laval wins SEK 50 million oil and gas order in Angola

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Initiated four years ago, the CLOV project is a shining example of successful teamwork. The inauguration provides the perfect opportunity to relive the three very intense days leading up to first oil. - See more at:

• Inauguration of CLOV in Angola

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The deal represents a deepening of the energy partnership between Russia and Europe based on the effectiveness of supply of a refinery located along the Druzhba pipeline. Total and Rosneft are further agreeing on an off-take agreement to supply Total's retail and wholesale customers securing stable supply to the premium Berlin and surrounding areas, markets and customers supplied by pipeline from the refinery.

Commenting on the signing Igor Sechin said: “This agreement is reflective of the level of trust, long-term commitment and mutual benefit in the relationships between Total and Rosneft. It proves the effectiveness of the European-Russian energy partnership in that it delivers added value to all companies and countries involved. As for Rosneft, this deal means a strengthening of its position in one of Europe's most efficient and effective refineries and an opportunity to serve the end-customers in its most important market. Once the deal is closed, Rosneft together with ROG will manage close to 55% of the refinery's ownership”.

Note for editors:

PCK Raffinerie GmbH refinery is located in the city of Schwedt/Oder in Brandenburg, Germany. Primary distillation capacity is 11.5 mln/t. Nelson index – 9.2. Shareholders: 37.5% ROG, 37.5% Shell, 16.67% Total, 8.33% Eni.

Technical-and-economic indexes of PCK refinery are one of the best in Europe.

In 2013 the overall Rosneft crude oil supplies to Germany accounted to 23.3 mln tones, which is 26% of all oil import of Germany.

In May 2011 Rosneft acquired a 50% share in Ruhr Oel GmbH (ROG) in Germany. ROG holds a share in 4 refineries in Germany (Gelsenkirchen – 100%, Bayernoil – 25%; MiRO – 24%; PCK– 37,5%). Moreover the joint venture holds stakes in 5 pipeline and sea crude oil terminals in the North, Baltic, Mediterranean and Adriatic Seas. Rosneft partner in the JV on a parity basis is BP Europa SE. ROG is the leader of German market in terms of refining volumes – 21.2 mln tones in 2013.

• Rosneft Acquires 16.67% Share in PCK Raffinerie GmbH

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“This success confirms Total’s exploration strategy in Iraq. The ongoing appraisal of the discoveries made on the Harir and Taza Blocks will allow us to identify options for development,” commented Marc Blaizot, Senior Vice President, Exploration at Total. “We are continuing exploration works on the Total-operated Safen and Baranan Blocks, with additional wells planned for 2015."

The Jisik-1 well encountered light oil of 43 API in a Jurassic carbonate reservoir. The well was tested with flow rates of 6,100 barrels per day of anhydrous oil, without stimulation.

Two other formation tests, both with flows rates of approximately 10-15 million cubic feet per day, confirmed the presence of gas reservoirs together with associated condensate in the Triassic.

Total has a 35% interest in the Harir Block, alongside Marathon Oil (45%, operator) and the Kurdistan Regional Government (20%).

Total in Iraq

Total has a 22.5% interest in the Halfaya field in Missan province. Phase 1 came on stream in June 2012 with a capacity of 100,000 barrels per day. Phase 2 began production in August 2014, and has since reached an output of 200,000 barrels. The revised contract plateau of 400,000 barrels per day could be reached in 2017.

In addition to its interest in the Harir Block, Total has a 20% interest in the Taza Block, and an 80% operated interest in the Safen and Baranan Blocks in the Kurdistan Region of Iraq.
- See more at: http://www.total.com/en/media/news/press-releases/total-announces-jisik-discovery-kurdistan-region-iraq#sthash.phXeayRa.dpuf

• Total Announces the Jisik Discovery in the Kurdistan Region of Iraq

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The Umm Lulu Oil Field is located approximately 30 km northwest of Abu Dhabi City. INPEX has jointly developed the Umm Lulu Oil Field with Abu Dhabi National Oil Company (ADNOC), BP and TOTAL.

In the first development phase, INPEX has commenced oil production from the Umm Lulu Oil Field by utilizing existing facilities of the Umm Al-Dalkh Oil Field, located adjacent to the Umm Lulu Oil Field. Full field development of the Umm Lulu Oil Field is currently in progress, and after completion, the field is expected to produce oil at a peak rate of 105,000 barrels per day.

The oil produced from the Umm Lulu Oil Field in the first development phase is transported via an existing subsea pipeline to Zirku Island, and eventually supplied to customers in Japan and other Asian countries as Upper Zakum Crude.

INPEX has been engaged in the oil development business through JODCO in Abu Dhabi for over 40 years. The company owns participating interests1 in the producing oil fields of Umm Shaif, Lower Zakum, Umm Lulu, Upper Zakum2, Umm Al-Dalkh and Satah. In addition, INPEX owns interests in the Nasr Oil Field under development. Through JODCO, INPEX has also been supporting local communities in Abu Dhabi through human resources development and other activities.

1. INPEX owns a 12% participating interest in the Umm Shaif, Lower Zakum, Umm Lulu, Nasr, Upper Zakum and Umm Al-Dalkh Oil Fields and a 40% interest in the Satah Oil Field.
2. The concession for the Upper Zakum Oil Field was extended until 2041, as announced on January 21, 2014.

• INPEX Commences Oil Production from Umm Lulu Oil Field Offshore Abu Dhabi, United Arab Emirates

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DONG Energy and Total have decided on a joint development of the Edradour and Glenlivet fields, by way of tie-in to the Laggan and Tormore infrastructure, with both fields expected to contribute to production in 2018.

Mike Smith, Managing Director for DONG Energy's oil and gas activities in the UK said:

"This is a great step forward for our business in the West of Shetlands. The agreement to move forward with the joint development of Edradour and Glenlivet underpins our long term gas hub strategy and strengthens our production base in the region."

• DONG Energy to divest 5% of West of Shetland Edradour field to Total - DONG Energy and Total to develop the Glenlivet and Edradour gas fields jointly

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Gina Krog is a field under development in the North Sea, sanctioned in 2013, with an expected production start-up early 2017. The project will produce 60,000 barrels of oil per day and 9 million cubic meters of gas per day at plateau. Following the sale, Total E&P Norge AS will retain a 30% interest in the Gina Krog field alongside Statoil (58.7%) and Det Norske (3.3%).

“This sale is in line with Total’s strategy of active portfolio management”, commented Patrice de Viviès, Senior Vice President Northern Europe, Exploration & Production. “With the Ekofisk South, Eldfisk II, Martin Linge and Gina Krog developments, Total’s production in Norway is set to grow between 2014 and 2017”.

• Norway: Total Sells An 8% Interest In Gina Krog Field And Interests In Three Minor Fields

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FMC Technologies' scope of supply consists of subsea equipment including manifolds and associated connections and controls equipment, wellhead systems, subsea tie back connection equipment and a subsea production tree.

"FMC Technologies is pleased to be supplying the subsea systems for the developments," said Tore Halvorsen, FMC Technologies' Senior Vice President, Subsea Technologies. "By working closely with Total we are able to provide a cost effective solution for developing these important fields."

• FMC Technologies Awarded Subsea Systems Contract for Total's Edradour and Glenlivet Fields

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