by Kristin Øye Gjerde, Norwegian Petroleum Museum
The question of who “owns” Ekofisk is not straightforward. In simple terms, however, the field and the rest of Norway’s continental shelf (NCS) belongs to the Norwegian state. This was determined on 14 June 1963, when the Storting (parliament) passed the Act Relating to Exploration for and Exploitation of Submarine Natural Resources. This permits licences to be awarded on certain terms.
— The Norwegian state "owns" Ekofisk, but many companies have had the rights to explore and exploit the natural resources at Ekofisk.
So it is more appropriate to ask which companies hold and have held rights from the state to explore for and exploit the natural resources in Ekofisk.
More specifically, that relates to interests in production licence (PL) 018. This was awarded in the first licensing round on the NCS in 1965.
The Phillips name has always been included among the licensees. But that is the only constant presence in the list of participants.
This article addresses how the licence composition has altered and how far these changes have been affected by developments in the oil industry generally and on the NCS in particular.
First licensing round, 1965
A single company, A P Møller, was given a sole concession in 1962 to explore for and produce oil on the Danish continental shelf for 50 years.
It is unlikely that anything similar could have happened in Norway, even though America’s Phillips Petroleum Company applied to the Norwegian government in 1962 for a similar licence.
In exchange, it offered to carry out seismic surveys worth NOK 1 million on the NCS. However, consideration of this request was put on hold.
The experience gained by the Norwegian authorities from giving hydropower concessions to domestic and foreign companies since the early 20th century meant nobody was going to get a sole licence.
Instead, the government announced a first licensing round on the NCS on 9 April 1965. The outcome on 17 August was that nine of 11 applicant groups were awarded a total of 74 blocks.
Norwegian industrial interests were then kept at arm’s length from the expensive and risky business of oil exploration, with two exceptions.
One was Norsk Hydro, which participated in the French-led Petronord group, and the other was the Norwegian Oil Consortium (Noco) in the Amoco-Noco team.
The Phillips group comprised the US company (51.74 per cent) with Fina Production Licenses AS (30 per cent) and Norsk Agip (18.26 per cent). It applied for and secured PLs 016, 017 and 018.
Exploring for oil was initially a very uncertain and expensive business. In addition to seismic surveys, the Phillips group had to charter a drilling rig.
That was required for a certain number of wells which the partners were committed to drill under the licence terms. They also had to pay the government an annual fee of NOK 50 000.
But the group had little idea that it had hit the jackpot. PL 018 covered blocks 1/5, where nothing has admittedly been found, 2/4 containing Ekofisk, 2/7 with Eldfisk, and 7/11 holding Cod.
A production licence on the NCS gives its holders the exclusive right to conduct exploration drilling for and production of petroleum deposits within a specified area. A production licence on the NCS gives its holders the exclusive right to conduct exploration drilling for and production of petroleum deposits within a specified area. Such licences are awarded by the Ministry of Petroleum and Energy to sets of licensees. These are comprise oil companies, with one designated as the operator to conduct operations on behalf of each group. Each licensee owns its proportionate share of the petroleum produced from the licence area. If a commercial discovery is made in the licence area, it can be developed by the licensees. This must be done on the basis of an approved plan for development and operation (PDO), which has been drawn up in accordance with the provisions of Norway’s Petroleum Act. Oil and gas which have not been produced remain the property of the Norwegian state.
The Phillips group pursued talks in 1967 with the Petronord group on a closer collaboration aimed at spreading risk more widely on the NCS.
These negotiation were initiated after other companies had drilled dry wells and spent a lot of money without seeming to have anything to show for it.
The outcome in 1968 was a swap of licence interests – a fairly common practice in the international oil industry. Phillips and Agip transferred 20 per cent of their holdings to Petronord in exchange for a similar proportion of the latter’s licences.
At the same time, agreement was reached that the two groups would share the cost of the Ocean Viking drilling rig and use it turn and turn about.
This brought a number of new licensees to PL 018 – Elf Norge AS (7.1 per cent), Total Norge (5.325 per cent), Aquitaine Norge AS (3.55 per cent) and Norsk Hydro Produksjon AS (2.5 per cent).
In addition, the minor French companies Eurafrep Norge AS, Coparex Norge AS and Cofranord AS each held a tiny fraction.
Fina retained 30 per cent, while Phillips reduced its share from 51.74 per cent to 36.96 per cent and Norsk Agip was cut from 18.26 to 13.04 per cent.
Rumours of a big discovery began to circulate in the autumn of 1969, with 25 October taken as the date when the geologists were sure a major find had been made in block 2/4. But Phillips did not officially report it to the government until 23 December.
This success was a good start for everyone who now held a stake in the licence, including Hydro. However, the interests Petronord passed to the Phillips group never yielded anything – which nobody could have predicted when the swap was made.
A press release on the Ekofisk discovery was finally issued on 2 June 1970. Meanwhile, the Norwegian government was seeking to secure a stronger involvement in NCS operations.
In deepest secrecy, the government bought up shares in Hydro on 9-15 December 1970 which ensured a majority state holding in the company.
This acquisition was officially approved by the Council of State on 22 January 1971, and gave the state a small stake in Ekofisk.[REMOVE]Fotnote: Hanisch, Tore Jørgen and Nerheim, Gunnar, Fra vantro til overmot?, Norsk oljehistorie, volume 1, Oslo, 1992: 165-166.
The Petronord deal had given Hydro an option to acquire 12 or 24 per cent of the group’s interest in a discovery.[REMOVE]Fotnote: Ibid. Holdings in PL 018 were therefore redivided again on 1 January 1971.
While the Phillips group retained its previous shares, Norsk Hydro Produksjon AS purchased interests from its Petronord partners which left it with 6.7 per cent of PL 018.[REMOVE]Fotnote: Elf Norge AS went down to 5.396 per cent, Total Norge to 4.047 per cent, Aquitaine Norge AS to 2.698 per cent, Eurafrep Norge AS to 0.456 per cent, Coparex Norge AS to 0.399 per cent and Cofranord AS to 0.304 per cent.
The next change in licensee composition occurred on 1 July 1977, when Elf and Aquitaine merged to form Elf Aquitaine Norge AS and thereby had an 8.094 per cent holding.
Statoil in and out
After the creation of Statoil in 1972, Norway’s state oil company built up a dominant position on the NCS with the right to a 50 per cent interest in new licences.
But many years were to pass before it secured a foothold in PL 018. That did not occur until 1988, when both international politics and major economic interests were involved.
The Troll gas sales agreement with a European consortium was the spark. Swapping licence interests between Statoil and France’s Elf and Total could provide the basis for this deal.
Estimated to contain 60 per cent of Norway’s gas reserves, Troll was proven in 1981 and declared commercial two years later. Nailbiting sales talks with continental gas buyers in 1985 were essential for developing the field.
These negotiations made slow progress, with the French particularly lukewarm. Something had to be done to persuade them to take a more positive view.
Elf and Total wanted licence interests in Troll and the Sleipner gas field. Could that be achieved, it might make the authorities in France more receptive to an agreement.
Statoil was therefore ready to enter into a swap which gave the French companies holdings in the two gas fields in exchange for a one per cent stake in Ekofisk.
Since it was difficult to estimate the value of this exchange, a net profit deal was also agreed – if revenues from one field exceeded a set value, the other party would be compensated.
The NOK 800 billion Troll gas sales agreement was entered into in May 1986, with the swap of licence interests coming into force on 1 April 1988.
This deal was considered important for securing French government approval of the sales agreement with Gaz de France, which was needed for a Troll go-ahead.[REMOVE]Fotnote: Reported by Ole-Johan Lydersen, a participant in negotiating the agreement, on 20 August 2019.
The advantage for Statoil of securing an interest in Ekofisk was the right this conferred to attend management committee meetings, providing it better insight into licence developments.
It gave the company control over the whole transport chain for gas exports, something which had concerned it ever since the Norpipe link from Ekofisk to Emden was installed in the 1970s.
During the 1980s, the Ekofisk Complex represented an important hub for Norwegian gas exports. The Ekofisk 2/4 S riser platform, operational from 1985, tied the Statoil-operated Statpipe transport system into Norpipe.
This installation was owned by Statoil but operated by Phillips. In 1998, the Statpipe-Norpipe line was relaid to bypass the Ekofisk Complex.
Another but less important reason why the state oil company wanted to know what was going on in PL 018 was the relationship between Tommeliten and Edda.
The former was a condensate field operated by Statoil which produced to the Phillips-operated Edda oil and gas field 12 kilometres away.
Following the oil price slump in 1985-86, Phillips – which had a 25 per cent interest in Tommeliten – became sceptical about developing it and withdrew from the project.
Statoil nevertheless secured acceptance in 1986 for a cheaper development solution based on subsea templates – which gave it useful experience with underwater technology.
Although Phillips had pulled out, it still wanted the Tommeliten wellstream to flow to Edda – not least because this field had proved half the size originally estimated.
That provided spare gas processing capacity. Moreover, the Tommeliten gas could be injected into the Edda reservoir to increase oil production.
The tie-in to Edda was implemented. According to Statoil, however, negotiating tariff terms between the Tommeliten and Ekofisk licences proved difficult.[REMOVE]Fotnote: Reported by Håkon Lavik, 15 August 2019.
Statoil’s interest in PL 018 changed again on 1 January 1999, when the government secured a five per cent stake for the state’s direct financial interest (SDFI) on the NCS.
Part of the Ekofisk II agreement with the Phillips group, this gave Statoil 5.95 per cent[REMOVE]Fotnote: Norwegian Petroleum Directorate, Facts, 2000. and resulted in a corresponding reduction in the holdings of the other licensees.
For the first time since 1968, Phillips saw its share of the licence reduced – but only from 36.96 per cent to 35.112 per cent.
Several reforms related to Norwegian state ownership in the petroleum sector were under way at this time. Plans for part-privatising Statoil to achieve greater flexibility internationally were initiated in 1999 and approved in 2001.
Another change was that administration of the SDFI, which had lain with the state company since 1985, was transferred in 2001 to a separate company called Petoro.
The latter took over various Statoil holdings in fields. Where the Greater Ekofisk Area was concerned, it acquired five per cent in PL 018 on 10 May 2001. That left Statoil with 0.95 per cent.
Total becomes biggest licensee
Crude prices slumped to a record low at the end of the 1990s, leaving the oil companies with acute profitability problems. They responded with mass redundancies and restructurings.
Larger entities provided greater strength in the market, improved cost control and better positioning in relation to the competition for reserves.
The turmoil which followed in the wake of these restructurings also affected the purchase and sale of interests in the Ekofisk licence.
Saga Petroleum, which acquired Norminol’s holding on 1 January 1995, disappeared on 11 January 2001. Its stake was taken over by Norsk Hydro Produksjon, which thereby rose to 6.654 per cent.
The French interests were gradually consolidated, with Eurafrep, Coparex and Cofranord being acquired in 1990 by Elf Rep, Elf Rex and Norminol respectively.
Elf Rep and Elf Rex then merged in the summer of 1992, and this company was incorporated in 1997 in Elf Petroleum – which thereby acquired 8.449 per cent of PL 018. Elf was merged into TotalFinaElf in the summer of 2000.
Just before Christmas that year, Total and Fina’s licence interests were merged with Total Norge’s holdings and thereby amounted to 31.87 per cent.
When these shares were then incorporated with TotalFinaElf’s, the result was a combined holding of 39.896 per cent. From 6 May 2003, TotalFinaElf was renamed Total E&P Norge AS.
This company then ranked as the largest licensee in PL 018, with the operator – now ConocoPhillips Skandinavia AS following the 2002 merger – in second place with 35.112 per cent.
Since Conoco had no stake in Ekofisk from before, its union with Phillips Petroleum did not contribute to increasing the company’s combined holding.
In addition, Italy’s Eni Norge AS took over Agip’s interests in the Greater Ekofisk Area on 15 December 2003.
Statoil merges with Hydro
After Petoro had acquired the bulk of Statoil’s interest in PL 018, a new change occurred in 2007 when the state company merged with Hydro’s petroleum and energy division.
From 1 October that year, StatoilHydro ASA held 0.95 per cent of the licence while StatoilHydro Petroleum had a 6.654 per cent interest.
These holdings were combined from 1 January 2009 into a 7.604 per cent stake held by StatoilHydro Petroleum AS. The company was renamed Statoil Petroleum AS on 2 November 2009.
The final change of name for this licensee occurred on 16 May 2018, when Statoil became Equinor. This was intended to signal that it embraced not only fossil fuels but also renewable energy sources such as solar and wind power.
A similar concept underlies the new company formed on 10 December 2018 by Eni Norge and Point Resources under the name Vår Energi AS.
“Vår” has a double meaning in Norwegian, denoting not only “Our Energy” but also springtime as a season of youth, freshness and greening.
Licence interest in 2019
On the 50th anniversary of the Ekofisk discovery in 2019, ConocoPhillips Skandinavia is operator for the field with a 35.11 per cent holding.
The other licensees at this time are Total E&P Norge AS (39.90 per cent), Vår Energi AS (12.39 per cent), Equinor Energy AS (7.60 per cent) and Petoro AS (five per cent).[REMOVE]Fotnote: Norwegian Petroleum Directorate fact pages, 13 August 2019.
Date of award
1 September 1965
31 December 2028
Original area (square kilometres)
Current area (square kilometres)
Published 23. September 2019 • Updated 7. October 2019
All the supplies needed to ensure that the offshore platforms can do their job of producing oil and gas pass through the base at Tananger outside Stavanger. Warehouse operation at the base covers five main functions: goods reception, spare parts store, accounting, pipe store and goods dispatch.
— Phillips is about to establish themselfs at the Norsco base,1972 Photo: Norsk fly og flyfoto/Norwegian Petroleum Museum
The contract for Phillips’ first supply base in Norway was signed with Stavanger-based tanker company Smedvig Tankrederi on 25 April 1966.
It covered the hire of outdoor storage and quay areas as well as a new combined warehouse and office building which was modest by today’s standards.
Located at Dusavik just outside Stavanger, Phillips ranked as the first tenant at what was to become one of the two big offshore supply bases in the district.
The drilling operations which led to the discovery of Ekofisk were served from Dusavik. While the lease ran until 1981, it only functioned as the main base for the Stavanger area until 1973.
Rapid organisational growth made the premises in Dusavik too small by that year, and additional space was obtained by taking a clearly creative approach.
So Phillips secured premises in a soap factory, a Chinese restaurant and the bar and other areas of Stavanger’s Alstor Hotel. And many of those hired in 1973 are sure to remember that they were interviewed at the city’s Atlantic Hotel.
Phillips base, 1973-81
Some activity had been established at the Aker Norsco base in Tananger during 1972, but it was not until the autumn of 1973 that the headquarters for Ekofisk was transferred from Dusavik.
That occurred with the occupation of the H Building at Tananger, where Phillips had signed a lease with the base company the year before.
This covered the hire of outside storage areas, quays, warehousing, a canteen and an office building – a complete supply base. All the buildings were purpose-built.
The lease gave Phillips an option to acquire the whole facility at a later date, which the company duly exercised in the summer of 1979.
To varying degrees since 1973, the operator has needed to lease both warehousing and offices from Aker Norsco – partly in temporary structures and partly in permanent premises.
From 1973 to 1976, exploration operations with the Ocean Viking rig continued to be run from the Dusavik base. The charter then expired, and remaining activities were moved to Tananger.
Lack of space at the latter premises meant that the training department was transferred to Dusavik and remained there until the lease expired in 1981.
Similar shortages meant extra premises had to be leased around Stavanger. This growing problem led to plans being laid from 1978 for a significant expansion at Tananger.
Phillips base since 1981
The new building was gradually occupied from December 1980 and formally opened in August 1981. Once it had been finished, the old H Building was completely refurbished to the same standard.
This expansion marked a significant improvement in working conditions for many employees, and helped to enhance efficiency by gathering much of the organisation under one roof.
The development was originally intended to meet all needs for office space, with the exception of the project department’s requirements.
However, it became clear even before the new building was occupied that this goal would not be reached. But it proved possible by and large to cease hiring space outside Tananger.
To deal with developments in the supply services for Ekofisk, Phillips entered into a contract with Aker Norsco on the construction of a larger and more modern warehouse.
This building and associated offices were occupied in late 1982/early 1983, and were regarded as a model example for the purpose.
The waterflooding project on Ekofisk received a green light in 1983, which created the need for more office space to accommodate the project department.
Since a quick start was important, the new building in Tananger was ready three months after the contract with Aker Norsco had been signed.
Premises utilised by Phillips in the Stavanger area by 1988 comprised 20 000 square metres of offices, 10 000 square metres of storage space and 850 square metres of workshops. In addition came the offices at Munkedamsveien in Oslo.
Another new building opened at the Tananger base in July 1996, which meant the whole workforce was assembled on one site in two connected premises.
While the old offices covered 14 000 square metres, the new seven-storey building has an area of 11 300 square metres and provides 420 additional office spaces.
It also accommodates a 600-square-metre conference centre, as well as a gym and a swimming pool measuring eight by 12.5 metres in the basement.
The Tananger base was sold in July 1996 to Aker Base, including buildings, furniture and fittings, and the deepwater quay.
Activities at the base
The Phillips base at Tanager plays a central role in operating the Greater Ekofisk platforms. All necessary supplies allowing these installations to do their job pass through it.
Warehouse operation at the base covers five main functions: goods reception, spare parts store, accounting, pipe store and goods dispatch.
The spare parts store is managed with the aid of a comprehensive computer system with full information for offshore personnel to log on directly and check availability.
When goods are received at the warehouse, they are marked with a purchase number and all data concerning the order is entered. They are packed out, checked and sent for shipment offshore.
The workshop, located in the same building as goods reception, deals with such jobs as mechanical repair of diesel engines, pumps, valves, heat exchangers and compressors.
It also repairs base equipment, like forklift trucks, cranes and fire-extinguishing systems. In addition, the shop produces pipework, pressure tanks and other structural welding.
The head office for Phillips’ activities in Norway stands alongside the supply base for the platforms in the Greater Ekofisk Area.
Published 29. July 2019 • Updated 22. October 2019
Oil and gas from the Greater Ekofisk Area is piped to Teesside in the UK and Emden in Germany respectively, where the pipeline terminals formed part of the field development. ConocoPhillips still operates the oil terminal in Teesside, while the facility in Emden has been taken over by Norwegian state-owned company Gassco.
— Gassterminalen i Emden. Foto: Husmo Foto/Norsk Oljemuseum
The terminal at Teesside in north-east England receives oil and natural gas liquids (NGL) by pipeline from the Ekofisk field. It comprises stabilisation, NGL fractionation, storage tanks for crude oil and an export port.
After arriving through the Norpipe Oil line, crude and NGL are separated and the oil goes through a stabilisation process before reaching the 10 storage tanks, which each hold 750 000 barrels.
The NGLs go to the fractionation facility, with a daily capacity of 64 000 barrels, for separation into methane, ethane, propane, and normal and iso butane.
While the methane (natural gas) is used to fuel the plant, the other products (now known as liquefied petroleum gases – LPG) are made liquid by cooling and stored for export by sea.
One reason for the choice of Teesside as the landfall for the Ekofisk pipeline was the opportunity it offered to install deepwater quays.
The terminal has four of these, with those for crude oil able to handle tankers up to 150 000 deadweight tonnes. The LPG quays can accept carriers loading as much as 60 000 cubic metres.
Two of the crude oil quays lie on the main channel of the River Tees, while the others have been installed in dredged docks.
Gas terminal in Emden
Gas arriving at the Emden terminal from the Ekofisk Complex enters nine parallel treatment trains for cleaning, metering and onward distribution to the buyers.
The North Sea gas is very clean, and needs only limited treatment to remove small amounts of sulphur compounds using an absorption process. Impure molecules from the gas accumulate on the surface of small particles, which act as filter spheres.
Each of the nine trains comprises four process columns and a process oven. The gas enters the top of a column and leaves through the base after passing through the filter spheres.
That leaves the gas ready for sale, and it is piped to the fiscal metering station before entering the buyer receiving pipelines and distribution network.
Three separate commercial pipeline systems connect to the terminal, operated by Ruhrgas, BEB and Gastransport Services (previously Gasunie) respectively. They pipe the gas away on behalf of the gas buyers.
The Norsea Gas Terminal in Emden was officially opened in September 1977 by Norwegian industry minister Bjartmar Gjerde and Phillips executive Gordon Goerin.
Ranking as the first gas sales deal for the Norwegian continental shelf, the Ekofisk agreement paved the way for later contracts covering other fields off Norway.
Regularity at the Emden terminal has been very high, with its own equipment never causing shutdowns. Maintenance takes place when other parts of the system are off line.
The terminal has a daily capacity of about 2.1 million cubic feet of gas per day.
Gas transport restructured
Norpipe AS owned the gas pipeline from Ekofisk to Emden until the transport system for the Norwegian offshore sector was restructured at 1 January 2003.
Norsea Gas A/S furthermore served as the formal owner of the Emden facility, with Phillips Petroleum and then ConocoPhillips as operator for both pipeline and terminal.
Since 2007, Norway’s state-owned Gassco company has been responsible for technical operation of the facilities on behalf of their owners.
That included operator responsibility for the H7 and B11 booster platforms along the gas pipeline, which were shut down in 2007 and 2013 respectively and have since been removed.
The Gassled partnership is a project collaboration embracing 10 companies which collective own large parts of the gas infrastructure on the Norwegian continental shelf (NCS).
A substantial proportion of Norway’s gas deliveries to Germany continues to arrive at the Emden terminal, including the volumes piped from Ekofisk.
Preliminary planning for a new terminal in the German port began in 2011, with Gassled taking the investment decision for this development in the autumn of 2012.
Construction work began in the following year, with the new facility being built on an unused part of the existing terminal site.
The new terminal has not expanded export capacity. But its functionality is well adapted to future processing needs for fields in the Greater Ekofisk Area and other parts of the NCS sending gas through the Norpipe system.
It was officially opened on 24 May 2016 by Elisabeth Aspaker, the Norwegian government minister for the EU and the European Economic Area. That closed a chapter in Ekofisk’s history.
Source: ConocoPhillips Norge
Published 29. July 2019 • Updated 12. October 2019
Two export pipelines run from the Ekofisk Complex. The one for gas has an external diameter of 36 inches and extends 443 kilometres to the German coastline. With an external diameter of 34 inches, the oil pipeline runs for 354 kilometres to Teesside in north-east England.
— Gas pipes at Ekofisk. Photo: Husmo Foto/Norwegian Petroleum Museum
In addition to ConocoPhillips’ own production from Ekofisk, these pipelines carry gas and oil from the company’s fields in the UK sector and from other fields on the Norwegian and British continental shelves.
The three fields in the Greater Ekofisk Area are also tied together by pipelines.
Oil pipeline to Teesside
The pipeline linking Ekofisk with the terminal for oil and natural gas liquids (NGL) at Teesside on the north-east English coast became operational in October 1975.
Pumps raise the pressure of the oil and NGL before they start their journey to land. Two pumping stations – 37/4 A and 36/22 A – originally stood along the pipeline to maintain this pressure, but have now been disconnected and removed.
The pipeline was installed with the ability to carry a million barrels per day. However, that much capacity has never been required.
In the UK sector, a 24-inch pipeline has been tied in with a Y connection to receive input from several British fields – including the J block developments operated by ConocoPhillips.
Output from the Greater Ekofisk Area is supplemented by crude from Valhall, Hod, Ula and Gyda heading for Teesside, optimising pipeline utilisation and thereby boosting value creation.
The pipeline is owned by Norpipe Oil AS and operated by ConocoPhillips.
Gas pipeline to Emden
This pipeline became operational in September 1977. The starting pressure of around 132 bar is provided by compressors on the Ekofisk Complex.
The 443-kilometre distance to Emden was split into three equal sections, with platforms B11 and H7 located at the intermediate points to provide boosting if required.
However, additional compression was seldom needed on the final stage to Emden. H7 was shut down in 2007 and B11 in 2013, and both have since been removed.
These two booster platforms were located in the German sector of the North Sea, while the pipeline also crosses the Danish sector.
The pipeline has been trenched or covered with sand. Its final section passes the island of Juist before making landfall on the coast of East Friesland to the north of Emden.
Its daily capacity is roughly 59.4 million standard cubic metres (2.1 billion cubic feet). In addition to gas from the Greater Ekofisk Area, it carries output from Valhall, Hod, Ula, Gyda and the Statpipe system (primarily Statfjord and Gullfaks).
Source: ConocoPhillips Norge
Published 29. July 2019 • Updated 12. October 2019
The Phillips group was awarded block 2/7 as early as 1965, and the Embla reservoir lies in the southern part of this acreage. Drilling began there in 1974 to depths of 4 500-5 000 metres, but pressure and temperature in the wells were too high for testing with the available equipment.
The first production well was not drilled and tested until 1988, followed by a second in 1990. Both yielded very promising results, and the field came on stream in May 1993.
Embla comprises a sandstone reservoir at least 250 million years old. The other fields in the Greater Ekofisk Area comprise fine-grained carbonate rocks deposited about 70 million years ago.
The Embla reservoir has a temperature of 160°C compared with the 125°C normally found in the chalk formations 1 000 metres higher up, and its pressure is almost twice as high.
Fabricated by Heerema in the Netherlands, the Embla 2/7 D jacket (support structure) was installed by the M 7000 crane vessel. It stands 84 metres high and weighs 2 300 tonnes.
A 5.2-kilometre subsea umbilical from Eldfisk comprises three power cables for electricity supply and eight fibreoptic lines handling data transmission and telecommunication.
The platform has six production wells and an average daily output of roughly 7 000 barrels of oil. All processing and metering took place on Eldfisk 2/7 FTP until 2015, and has now been switched to Eldfisk 2/7 S.
A 14-inch flowline linked 2/7 D with 2/7 FTP and runs today to 2/7 S. Produced at Wick in Scotland, this line was floated out to the field in one piece.
Topside equipment includes the wellhead area, helideck (built by Vindholmen Services in Arendal), crane, control room, workshop, test separator and glycol pump.
Normally unmanned, the platform is maintained as and when required and therefore incorporates a simplified accommodation module with lounge, mess, coffee room, galley, changing room, WC and 12 emergency beds.
Published 24. June 2017 • Updated 25. October 2019