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2014 Financial TransparencyExample of Total in Norway(Données 2013)

COMMITED TO BETTER ENERGY

Financial Transparency Example of Total in Norway

The contractual framework of Total’s operations in Norway Since the late 1960’s, Total has played a major role in the discovery and development of several fields on the Norwegian continental shelf, including the giant Ekofisk field, still producing at important levels. TOTAL E&P NORGE AS holds as of 31 December 2013 interests in 103 production licenses, 31 of which it operates. TOTAL E&P NORGE AS is one of the largest contributors to the Group’s production with 243 kilo barrels of oil equivalents per day (kboe/d) in 2013, representing approximately 8% of the Norwegian production and 11% of Total’s production.

License portfolio of TOTAL E&P NORGE AS The following table presents all TOTAL E&P NORGE AS licenses as per December 31, 2013. All licenses are subject to concession contracts.

(PL= Production License)

License Field Total’s interest in the license

(%)

Total’s entry date in the license

Total’s role

PL006 Tor 100.00 02.25.1992 Operator

PL018 Ekofisk area 39.90 09.01.1965 Partner

PL018B Albuskjell 39.90 08.25.1995 Partner

PL024 Frigg 47.13 05.23.1969 Operator

PL026 Rind* 62.13 05.23.1969 Operator

PL029 B Gina Krog** 30.00 01.01.2012 Partner

PL029 C Gina Krog** 100.00 12.03.2012 Operator

PL034 Tune 10.00 07.01.1999 Partner

PL036 Vale 24.24 03.23.1972 Partner

PL036 BS Heimdal 16.76 10.13.2003 Partner

PL036 D Vilje 24.24 10.17.2008 Partner

PL040 Martin Linge*** 51.00 04.01.1975 Operator

PL043 Martin Linge*** 51.00 10.16.1990 Operator

PL043BS Martin Linge*** 51.00 01.06.2006 Operator

PL043CS Islay 100.00 12.05.2010 Operator

PL043DS Islay 100.00 12.05.2010 Operator

PL044 Tommeliten* 15.00 08.27.1976 Partner

PL046 Sleipner 10.00 01.01.1987 Partner

PL046B Volve 10.00 11.28.2006 Partner

PL046C ‘H-Discovery’* 10.00 12.21.2011 Partner

PL046D - 10.00 02.03.2012 Partner

PL048 Gina Krog** 21.80 02.18.1977 Partner

PL048B Glitne 21.80 01.10.2001 Partner

PL048E Eirin* 21.80 09.12.2010 Partner

PL051 Huldra 24.50 05.25.1990 Partner

PL052B Huldra 18.00 11.30.2001 Partner

PL053 Oseberg Øst 14.70 04.06.1979 Partner

PL054 Troll 3.69 01.01.1987 Partner

PL055C Oseberg Øst 14.70 11.18.2003 Partner

PL062 Åsgard 24.50 07.01.1991 Partner

PL064 Snøhvit 5.00 03.27.1981 Partner

PL072C Beta &Theta* 10.00 12.21.2011 Partner

PL073 Tyrihans 29.14 04.01.1993 Partner

PL073B Tyrihans 26.67 12.17.2004 Partner



PL079 Oseberg Sør 14.70 03.19.2002 Partner

PL085 Troll 3.69 01.01.1987 Partner


PL085B Troll 3.00 09.11.1992 Partner

PL085C Troll 3.69 01.25.2002 Partner

PL092 Mikkel 7.65 01.01.2004 Partner


PL094B Åsgard 7.68 06.14.2002 Partner


PL100 Albatross 35.00 03.09.1984 Partner

PL102 Skirne 40.00 03.01.1985 Operator

PL102C Atla 40.00 03.20.2009 Operator

PL102D - 40.00 02.03.2012 Operator

PL102E Skirne 40.00 02.03.2012 Operator

PL102F Trell * 40.00 10.10.2013 Operator

PL102G - 40.00 10.10.2013 Operator

PL104 Oseberg Sør 14.70 03.19.2002 Partner

PL104B Oseberg Sør 14.70 02.03.2012 Partner


PL110B Tornerose* 18.40 12.17.2004 Partner

PL110C Snøhvit 18.40 04.28.2006 Partner

PL120 Visund 11.00 08.23.1985 Partner

PL120B Gimle 11.00 10.06.2006 Partner

PL121 Mikkel 7.65 01.01.2004 Partner

PL127 Alve Nord* 50.00 02.28.1986 Operator


PL134B Kristin 6.00 01.14.2000 Partner

PL134C Morvin 6.00 01.06.2006 Partner

PL146 King Lear* 22.20 07.08.1988 Partner

PL171B Oseberg Sør 10.00 03.19.2002 Partner

PL190 Tune 10.00 01.01.1997 Partner

PL190B - 10.00 02.08.2013 Partner

PL193 Kvitebjørn 5.00 01.02.1997 Partner

PL193C Kvitebjørn ext. 5.00 02.04.2011 Partner

PL193E Kvitebjørn 5.00 02.03.2012 Partner

PL199 Kristin 6.00 01.02.2004 Partner

PL211 Victoria* 40.00 02.02.1996 Operator

PL211B Victoria* extension 40.00 02.16.2007 Operator

PL219 - 15.00 02.02.1996 Partner


PL249 Vale 24.24 06.04.1999 Partner

PL255 Linnorm* 20.00 05.12.2000 Partner

PL257 Erlend* 6.00 01.01.2004 Partner

PL263C Yttergryta ext. 24.50 04.19.2008 Partner

PL275 39.90 03.15.2002 Partner

PL303B Beta&Theta* 10.00 05.27.2011 Partner

PL333 King Lear* 22.20 12.17.2004 Partner

PL395 Ververis * 10.00 09.30.2013 Partner


PL479 Smørbukk North* 9.80 02.29.2008 Partner

PL535 Norvarg* 40.00 05.15.2009 Operator

PL535B Norvarg extension* 40.00 06.21.2013 Operator

PL554 Garantiana* 40.00 05.31.2011 Operator

PL554B Garantiana* 40.00 05.31.2011 Operator

PL569 Theta NE* 10.00 02.04.2011 Partner

PL574 - 30.00 02.04.2011 Partner

PL585 - 100.00 02.04.2011 Operator

PL618 - 60.00 02.03.2012 Operator

PL619 - 50.00 02.03.2012 Operator

PL627 - 40.00 02.03.2012 Operator


PL661 - 60.00 02.08.2013 Operator

PL662 - 60.00 02.08.2013 Operator

PL667 - 50.00 02.08.2013 Operator

PL675 - 40.00 02.08.2013 Partner

PL676S - 20.00 02.08.2013 Partner

PL684 - 5.00 02.08.2013 Partner

PL685 - 40.00 02.08.2013 Operator

PL710 - 40.00 06.21.2013 Operator

* Undeveloped discoveries ** Former Dagny ***Former Hild

Martin

Linge


Total’s production and projects in Norway (1)

Total’s SEC* Production

Year Total Liquids Natural gas

kboe/d kb/d Mcf/d

2011 287 172 619

2012 275 159 622

2013 243 136 575

* SEC : Securities and Exchange Commission

In Norway, where the Group has had operations since the mid-1960s, TOTAL has equity stakes in 103 production licenses on the Norwegian continental shelf, 31 of which it operates. In 2013, the Group’s production was 243 kboe/d, with 74 kboe/d from the Greater Ekofisk Area located in the southern sector of the North Sea, 103 kboe/d from the central and northern portions of the North Sea and 66 kboe/d from the Haltenbanken region (in the Norwegian Sea) and the Barents Sea. The Group’s production in Norway in 2012 was 275 kboe/d and 287 kboe/d in 2011. The decrease in production between 2011 and 2013 was mainly due to the decline of mature fields. Production should increase again and reach a level of around 300 kboe/d at the horizon 2017 with the start-up of several new fields, the developments of which have been launched (Martin Linge, Ekofisk South, Eldfisk II). – In the Norwegian North Sea, the most substantial contribution to the Group’s production, which is for

the most part non-operated, comes from the Greater Ekofisk Area (e.g., Ekofisk, Eldfisk, Embla). • In the southern Norwegian North Sea: In the Greater Ekofisk Area, the Group owns a 39.9% stake in the Ekofisk and Eldfisk fields. The Ekofisk South and Eldfisk 2 projects, each with a capacity of 70 kboe/d, were launched in 2011. Production at Ekofisk South started in October 2013, while start-up at Eldfisk 2 is expected in early 2015. The project relating to the construction and installation of the new Ekofisk accommodation and field services center platform has now been completed and the accommodation has been operational as of November 2013. • In the central part of the Norwegian North Sea: Gas production start-up at the Atla field, located on license PL102C (40%, operator) and Beta West field (10%), a satellite of Sleipner, took place in October 2012 and April 2011, respectively. The development of the Gina Krog structure (38%), formerly known as Dagny and located to the north of Sleipner, was approved in 2013. Production start-up is planned for 2017. On license PL036D (24.24%), the fast-track development of Vilje South was launched in 2011. Production start-up is expected in the first half of 2014.

• In the northern part of the Norwegian North Sea: The Islay field (100%, operator) was put into production in 2012. This field extends on each side of the Norwegian/Great Britain border and the Group’s interest in the Norwegian part is 5.51%. The Stjerne field, located on license PL104 (14.7%), and Visund South field, located on license PL120 (7.7%), were put into production in July 2013 and November 2012, respectively. On license PL120 (7.7%), the fast-track development of Visund North, which started in late 2011, made it possible to start production on the field in November 2013. On the Greater Hild Area (51%, operator), located in the north, the Martin Linge development scheme was approved by the authorities in 2012, with production start-up scheduled end 2016 at an estimated capacity of 80 kboe/d.

(1)

The information stated in above paragraph is extracted from 2013 Registration Document submitted to the Financial Market Authority (AMF) on the 27

th of March 2014.


The Oseberg Delta phase 2 project (14.7%), located on production licenses PL104 and PL79, was approved by the authorities in October 2013 and production start-up is planned for 2015.

– In the Norwegian Sea, the Haltenbanken area includes the Tyrihans (23.2%), Linnorm (20%), Mikkel (7.7%) and Kristin (6%) fields as well as the Åsgard field (7.7%) and its satellites Yttergryta (24.5%) and Morvin (6%). The Åsgard sub-sea compression project, which will increase hydrocarbon recovery on the Åsgard and Mikkel fields, was approved by the Norwegian authorities in 2012. All the main contracts have been awarded. Development of the Linnorm gas field is still under study following the lower than expected results obtained at the Onyx South exploration well, which was drilled in 2013. It was planned to export the gas from Linnorm to the Nyhamna onshore terminal by installing a new pipeline (Polarled project). The Polarled project (5.11%) was approved in December 2012. The project consists of the installation of a 481 km long pipeline from the Aasta Hansen field to the Nyhamna terminal and in the expansion of the terminal.

– In the Barents Sea, a project intended to improve the performance of the Snøhvit liquefaction plant (18.4%, capacity of 4.2 Mt/y) was launched in 2012. This plant is supplied with gas from the Snøhvit, Albatross and Askeladd fields.

Several exploration wells were successfully drilled on a number of licenses during the 2011-2013 period and revealed the presence of hydrocarbons at the structures of Smørbukk North (PL479, 7.68%) and Rhea (PL120, 7.68%) in 2013, Garantiana (PL554, 40%, operator) and King Lear (PL146 and 333, 22.2%) in 2012, and Alve North (PL127, 50%, operator) and Norvarg (PL535, 40%, operator) in 2011. The Novarg appraisal well drilled in 2013 confirmed the presence of gas in the structure, but the well results, which were under study as of December 31, 2013, are below expectations. In addition, the Group is continuing to optimize its asset portfolio in Norway by obtaining new licenses and divesting a number of non-strategic assets.

Taxes

In 2013, the government received through its agencies a total amount of tax of NOK 18,905 million (3,216 million dollars*) from TOTAL E&P NORGE AS of which 100% was Petroleum Tax, compared to NOK 27,360 million (4,701 million dollars**) in 2012 and NOK 22,488 million (4,016 million dollars***) in 2011.

* 2013 exchange rate: 1 USD = NOK 5.89 **2012 exchange rate: 1 USD = NOK 5.82 *** 2011 exchange rate: 1 USD = NOK 5.60

EITI (Extractive Industries Transparency Initiative) in Norway After having been accepted as a candidate country on February 11, 2009, Norway was validated by the board of EITI as an EITI compliant country on March 01, 2011. This status will have to be validated again by February 29, 2016. It must be noted that the stakeholders in the validation process may request a new validation from the EITI Board at any moment before that date if they consider that the status of the country needs to be reviewed. The audit firm Deloitte has been in charge of the task of receiving and reconciling the reported figures from companies and authorities. Five reports have been published (for payments in 2008, 2009, 2010, 2012). The deadline for next EITI report is fixed on December 31, 2015. Furthermore, a stakeholder group was created, involving relevant actors such as authorities, industry and civil society. Members of the multi-stakeholder group are appointed for two years by the King-in-Council. On 30 January 2012, the Norwegian EITI multi-stakeholder group was appointed. A new multi-stakeholder group will be appointed in 2014.


The reporting requirements for the companies and government agencies were passed into law under the “Regulation on reporting and reconciliation of revenue flows from petroleum activity” text that went into effect on 1st July 2009.

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