Denmark

In Denmark, Total was awarded in June 2010 an 80% interest in and the operatorship for licenses 1/10 (Nordjylland) and 2/10 (Frederoskilde), following the approval by the Danish Energy Agency. These onshore licenses cover areas of 3,000 km2 and 2,300 km2, respectively, and are expected to be appraised for shale gas.

France

Italy

Norway

•  In the Norwegian Sea, the Haltenbanken area includes the Tyrihans (23.2%), Mikkel (7.7%) and Kristin (6%) fields as well as the Åsgard (7.7%) field and its satellites Yttergryta (24.5%) and Morvin (6%). Morvin started up in August 2010 as planned, with two producing wells. In 2010, the Group’s production in the
  Haltenbanken area was 61 kboe/d.
  
• In the Barents Sea, LNG production on Snøhvit (18.4%) started in 2007. This project includes development of the natural gas fields, Snøhvit, Albatross and Askeladd, as well as the construction of the associated liquefaction facilities. Due to design problems, the plant experienced reduced capacity during the start-up phase. A number of maintenance turnarounds were scheduled to fix the issue and the plant is now operating at its design capacity (4.2 Mt/y).
  

Between 2008 and 2010, exploration and appraisal work was carried out on various licenses. In the Norwegian North Sea, the oil discovery on Dagny (PL 048, 21.8%) and the Pan/Pandora (PL 120, 11%) discovery, made in 2008, substantially increased the potential of the Sleipner and Visund areas, respectively. Pan/Pandora is to be developed as a fast track satellite. The development project is expected to be launched in 2011 after receipt of approval from the Norwegian authorities. The Dagny project is scheduled for approval in 2012.

A number of discoveries were made in 2009, in particular on Beta Vest (PL 046, 10%) near Sleipner, Katla (PL 104, 10%), located south of Oseberg, and Vigdis North East (PL 089, 5.6%), located south of Snorre. Katla and Vigdis North East are expected to be developed as fast track satellites, with the approval of the projects by the partners on both licenses planned for the first half of 2011.
In the Central North Sea, Total(40% operator) made a gas and condensate discovery in 2010 on the David structure (PL 102C-Heimdal area). The structure could be developed through a tieback to Heimdal via Skirne-Byggve. In the Barents Sea, Total was awarded in 2009 a new exploration license - PL 535 (40%) - during the twentieth licensing round. On this license, a 3D seismic acquisition was completed in 2009 and drilling is expected to begin in 2011. In 2011, Total was awarded four new exploration licenses, including one for which Total is operator, during the 2010 APA (Awards in Predefined Areas).

Netherlands

In the Netherlands, Total has been active in natural gas exploration and production since 1964 and currently holds twentyfour offshore production permits, including twenty that it operates, and an offshore exploration permit, E17c (16.92%), awarded in February 2008. In 2010, the Group’s share of production amounted to 42 kboe/d, compared to 45 kboe/d in 2009 and 44 kboe/d in 2008.
In 2008, Total acquired Goal Petroleum (Netherlands) B.V.

• On the K5F field (40.39%, operator), production began in September 2008. This project is comprised of two sub-sea wells connected to the existing production and transport facilities. K5F is the first project in the world to use only electrically driven sub-sea wellheads and systems. This advance in sub-sea technologies is expected to increase the reliability of systems and improve environmental performance.
  
• The development of the K5CU project (49%, operator) was launched in 2009 and production started up in early 2011. This development includes four wells supported by a platform that
  has been installed in September 2010 and is connected to the K5A platform by a 15 km gas pipeline.
  

In late 2010, Total disposed of 18.19% of its shares in the NOGAT gas pipeline and decreased its interest to 5%.

United Kingdom

In the United Kingdom, Total has been present since 1962 with production in 2010 of 207 kboe/d, compared to 217 kboe/d in 2009 and 213 kboe/d in 2008.  The United Kingdom accounts for nearly 10% of the Group’s overall production. 86% of this production comes from operated fields located in two major zones: the Alwyn zone in the northern North Sea, and the Elgin/Franklin zone in the Central Graben.

• On the Alwyn zone, start-up of satellite fields or new reservoir compartments allowed production to be maintained. The processing and compressing capacities of the Alwyn platform increased from 530 Mcf/d to 575 Mcf/d during the summer of 2008 planned shutdown for maintenance. The N52 well drilled on Alwyn (100%) in a new compartment of the Statfjord reservoir came onstream in February 2010 with initial flow of 15 kboe/d (gas and condensates).
  The Jura field (100%), discovered in late 2006, started production in May 2008 through two sub-sea wells connected to the pipeline linking Forvie North and Alwyn. The production capacity of this field is 50 kboe/d (gas and condensates).
  
  Development studies were completed on Islay (100%), a second gas and condensates discovery made in 2008 and located in a faulted panel immediately east of Jura, and the development was approved in July 2010. Start-up of production is expected in the second half of 2011 with a production capacity of 15 kboe/d.
  
  In late 2008, Total increased its interest in the Otter field from 54.3% to 81%. An agreement to dispose of this interest was reached in 2010 and is expected to be completed under two phases between 2011 and 2012.
  
• The development of the Elgin (35.8%) and Franklin fields (35.8%), in production since 2001, made a substantial contribution to the Group’s operations in the United Kingdom. This project constituted a technical milestone, combining the development of one of the deepest reservoirs in the North Sea (5,500 m) with temperature and pressure conditions among the highest in the world (190°C and 1,100 bars).
  
  On the Elgin field, the infill well drilled between November 2008 and September 2009 started production in October 2009 at a rate of 18 kboe/d. Drilling of a second infill was completed in 2010 with production of 12 kboe/d starting up in May.Drilling of such a well in a high pressure/high temperature depleted field is a major technical milestone. Additional development of West Franklin through a second phase (drilling of three additional wells and installation of a new platform connected to Elgin) was approved in November 2010. This phase is expected to result in the development of approximately 85 Mboe in 100%. Start-up of production is expected at yearend 2013.
  
  As part of an agreement signed in 2005, Total acquired a 25% interest in two blocks located near Elgin and Franklin by drilling a successful appraisal well on the Kessog structure. This interest was increased to 50%.
• In the West of Shetland area, Total increased its interest to 80% in the Tormore and Laggan fields in early 2010. 
  The final investment decision for the Laggan/Tormore project was made in March 2010 and commercial production is scheduled to start in 2014 with an expected capacity of 90 kboe/d. The joint development scheme selected by Total and its partner includes sub-sea production facilities and off-gas treatment (gas and condensates) at a plant located near the Sullom Voe terminal in the Shetland Islands. The gas would then be exported to the Saint-Fergus terminal via a new pipeline connected to the Frigg pipeline (FUKA).
  In 2010, the Group’s interest in the P967 license (operator), which includes the Tobermory gas discovery, increased to 50% from 43.75%. This license is located north of Laggan/Tormore.
  In early 2011, a gas and condensate discovery was made on the Edradour license (75%, operator).

Total holds interests in ten assets operated by third parties, the most important in terms of reserves being the Bruce (43.25%) and Alba (12.65%) fields. The Group disposed of its interest in the Nelson field (11.5%) in 2010.

Source : Registration Document 2010