Elgin–Franklin fields
| Elgin–Franklin field | |
|---|---|
 |
|
| Country | Scotland, United Kingdom |
| Location | North Sea |
| Block | 22/30b 22/30c 29/5b |
| Offshore/onshore | Offshore |
| Coordinates | Lua error in package.lua at line 80: module 'strict' not found. |
| Operator | Total S.A. |
| Partners | Total S.A. Eni BG Group E.ON ExxonMobil Chevron Corporation Dyas Oranje-Nassau Energie |
| Field history | |
| Discovery | 1985 (Franklin) 1991 (Elgin) |
| Start of production | March 2001 (Elgin) August 2001 (Franklin) |
| Production | |
| Current production of oil | 45,000 barrels per day (~2.2×106 t/a) |
| Recoverable oil | 365 million barrels (~4.98×107 t) |
| Estimated gas in place | 1,710×109 cu ft (48×109 m3) |
| Producing formations | Upper Jurassic Fulmar Formation (Franklin Sand) |
The Elgin–Franklin fields are two adjacent gas condensate fields located in the Central Graben Area of the North Sea 240 kilometres (130 nmi) east of Aberdeen, Scotland at a water depth of 93 metres (305 ft). The joint development of the Elgin and Franklin fields is the largest high pressure high temperature development in the world, and also contains the world's hottest, highest temperature field, West Franklin, and the Glenelg field. On 25 March 2012, a gas leak occurred at the Elgin platform resulting in a shut down of production and evacuation of personnel. The leak continued for over seven weeks, and was stopped after well intervention work on 16 May 2012. Production from the fields restarted almost a year later, on 9 March 2013.
Contents
History
The Franklin field was discovered by well 29/5b-4, drilled by Ultramar in 1985, and appraised by wells 29/5b-6z in 1989/1990 and 29/5b-8 in 1991.[1] The field was named after British Explorer Sir John Franklin, and first production was in August 2001.[2]
The Elgin field was discovered by well 22/30c-8 in 1991 and appraised by wells 22/30c-10 in 1992/1993 and 22/30c-13 in 1994, drilled by Elf Aquitaine. The field was named after the Scottish town of Elgin. Production from the Elgin field began in March 2001.[2]
The Glenelg satellite field was discovered in 1999 by well 29/4d-4, drilled by Total.[3] It is named after the Scottish town of Glenelg, Highland. It was developed by a step-out well drilled from the Elgin platform and first production was in March 2006.[4]
The West Franklin reservoir was discovered by Total in 2003. It was developed by a deviated well from the Franklin platform. First production was achieved in March 2007 with the second well coming on stream in September 2008.[5]
March 2012 gas leak
On 25 March 2012 a gas leak occurred at the Elgin Well head platform within well 22/30c-G4 during operations to plug and decommission the well.[6] No injuries were reported and 219 non-essential personnel were evacuated from the PUQ and the adjacent Rowan Viking jack up drilling rig, which was performing the decommissioning work. The remaining 19 personnel were evacuated later on the same day.[7]
At the time of the incident the fields were producing 120,000 barrels per day (19,000 m3/d) of oil equivalent, about 7% of the UK's gas production.[8] Methane gas was released into the environment as was between two and 23 tonnes of condensate which formed a sheen on the sea surface measuring approximately 6 nautical miles (11 km; 6.9 mi) in length. The HM Coastguard declared a 2 nautical miles (3.7 km; 2.3 mi) exclusion zone for ships and a 3 miles (4.8 km) exclusion zone for aircraft. Shell E&P also evacuated non essential staff from the separate Shearwater platform located in block 22/30b 6 km (3.2 nmi) from Elgin.[9] At its peak, 200,000 cubic metres per day (7,100,000 cu ft/d) of gas was being released, which slowed when a relief well was drilled. The platform flare was alight till 31 March 2012 representing a potential risk of ignition for the leaking gas if wind direction should change. Total announced the flare spontaneously shut down on Saturday 31 March 2012 after exhaustion of the volatile residues within the PUQ processing facilities which it was burning. The leak was stopped following well intervention work on 16 May 2012, which involved pumping mud and cement into the well.[10]
The cause of the incident was identified as corrosion in the casing of the G4 well, and a sudden release of gas from the Hod formation above the producing reservoir.[11] Total identified the origin of the gas leak to be an unexploited chalk reservoir layer of the Hod formation located at a depth of 4,500 metres (14,800 ft), above the main reservoir, which was supported by analysis showing the absence of significant concentration of hydrogen sulfide in the gas. The Hod formation had been isolated by steel casing during drilling in 1997. On 25 February 2012 an increase in pressure was observed in the C annulus within the well and remedial operations started on 4 March 2012. Total believe that the C annulus failed and gas was observed leaking from the 30-inch (760 mm) conductor.[12]
An inspection team comprising eight people from Total and Wild Well Control, a specialist well control company, boarded the Elgin platform on 5 April 2012 to gather information about the state of the platform. The team left safely after four hours.[13]
During April 2012 a diverter assembly was installed around the G4 well head to divert the leaking gas (estimated then at 200,000 cubic metres per day (7,100,000 cu ft/d)) away from the platform in a controlled manner enabling well control operations to begin.[14] In May 2012 two drilling rigs were working on repairing the leak. The West Phoenix semi submersible rig was working on the "top kill" operation. This involved pumping weighted drilling mud into the well via the wellhead assembly, a method which was ultimately successful in halting the leak. A relief well, G4-K1 was drilled to "bottom kill" the well by the Sedco 714.
Eleven monitoring overflights of the area by surveillance aircraft from Oil Spill Response Limited were made in early May, and the flow rate from the well was estimated at that time to be 50,000 cubic metres per day (1,800,000 cu ft/d).[15]
On 16 May Total announced that the leak had been stopped.[16]
Production restarted on 9 March 2013.
Ownership
The fields are operated by Total E&P UK Limited, a subsidiary of Total S.A.(formerly Elf Aquitaine).
Elgin-Franklin and West Franklin
Equity in Elgin and Franklin was fixed by a unitisation agreement between three partner groups, and is shown in the table below.[2] West Franklin is owned by the same partnership.
| Company | Equity | Note |
|---|---|---|
| Total | 35.784% | Operator (formerly Elf) held via EFOG joint venture |
| Eni | 21.867% | |
| BG Group | 14.110 % | |
| GDF Suez | 10.389% | held via EFOG joint venture |
| E.ON Ruhrgas | 5.200% | |
| Exxon Mobil | 4.375% | |
| Chevron | 3.900% | formerly Texaco |
| Dyas UK Limited | 2.1875% | |
| Oranje-Nassau (U.K.) Limited | 2.1875 % |
E.F. Oil and Gas Limited (EFOG), is a company in which the shares are held 77.5% by Elf Exploration UK Limited and 22.5% by GDF Suez.
Glenelg
The partners in the Glenelg field are shown below.[4]
| Company | Equity | Note |
|---|---|---|
| Total | 49.47% | Operator (formerly Elf) |
| E.ON Ruhrgas | 18.57 % | |
| BG Group | 14.70% | |
| GDF Suez | 9.26% | |
| Eni (UK) Limited | 8.00% |
Geology
Franklin field
The Franklin field is a tilted fault block with little internal faulting. The main reservoir is the Upper Jurassic (Oxfordian Age) Fulmar sandstone which has porosities in excess of 20%. The Middle Jurassic Pentland formation forms a second reservoir with a separate hydrocarbon pool. The reservoir is at 5,500 metres (18,000 ft) depth. It is at pressures of 14,000 psi (97,000 kPa) and temperatures of 190 °C (374 °F). Originally the recoverable reserves for Franklin were estimated at 820 billion cubic feet (23 billion cubic metres) of natural gas and 120 million barrels (19×106 m3) of condensate.[17]
Elgin field
The Elgin structure is a fault bounded high on top of a collapsed Triassic mud "pod". It is heavily faulted and split into several separate fault panels with discrete gas water contacts. The reservoir is the same Fulmar sandstone as Franklin. The Pentland reservoir at Elgin is of poorer quality than that underneath Franklin and has not been developed. The original estimate of recovrable reserves for Elgin was 890 billion cubic feet (25 billion cubic metres) of gas and 245 million barrels (39.0×106 m3) of condensate.[17]
West Franklin
The West Franklin structure has a Fulmar formation reservoir.
Glenelg
The Glenelg field is a tilted fault block with a Fulmar formation reservoir.
Development
The Elgin-Franklin development is located in the Central Graben Area of the North Sea 240 kilometres (130 nmi) east of Aberdeen, Scotland at a water depth of 93 metres (305 ft). The installation consists of three separate platforms, two of which are connected by a 90 m (300 ft) bridge: two wellhead platforms which house the wells, one each for the Elgin and Franklin reservoirs, and the process, utilities and quarters (PUQ) platform, which is the central processing platform. The PUQ is a pile mounted jack up design which contains hydrocarbon processing facilities, control systems and accommodation for the crew of 97. The structure was built by BARMAC in Nigg, Scotland, and installed in July 2000. The facility has a processing capacity of 516 million cubic feet per day (14.6×106 m3/d) of gas and 175 thousand barrels per day (27.8×103 m3/d) of condensate.[18]
The Franklin wellhead platform has nine well slots. It is not normally manned but has a helideck and shelter for up to 20 people. The Elgin wellhead platform has 12 well slots. The platforms are linked to the PUQ by flowlines and were installed in 1999. The WHP has no installed drilling facilities (derrick, etc.). Well drilling and workover services are provided when needed by a jack up rig which operates in tender mode.
The Produced oil is transported through the Forties pipeline system to BP's Kinneil terminal in Grangemouth while produced gas is transported through the SEAL Pipeline to Bacton, Norfolk.
Reservoir characteristics
- high pressure / high temperature (HP/HT) wells
- well depth: 5,500 m (3.4 mi)
- pressure range: 600 – 1100 bar
- operational pressure: 860 bar
- fluid temperature: 193 °C (379 °F)
- sea floor depth: 93 m (305 ft)
The West Franklin reservoir is the world's hottest, highest pressure reservoir, with a temperature of 197 °C (387 °F) and pressure of 1,155 bars (115,500 kPa).[1]
See also
References
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External links
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