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{{Short description|Fossil fuel deposit in the North Sea}}
{{Infobox oil field
{{Infobox oil field
| name = Elgin–Franklin field
| name = Elgin–Franklin field
Line 8: Line 9:
| coordinates = {{coord|57|10|N|2|00|E|type:waterbody_region:GB|display=inline,title}}
| coordinates = {{coord|57|10|N|2|00|E|type:waterbody_region:GB|display=inline,title}}
| coordinates_ref =
| coordinates_ref =
| relief = yes
| country = [[Scotland]], United Kingdom
| country = [[Scotland]], United Kingdom
| region =
| region =
| location = [[North Sea]]
| location = [[North Sea]]
| block = 22/30b<br/>22/30c<br/>29/5b
| block = 22/30b<br />22/30c<br />29/5b
| offonshore = Offshore
| offonshore = Offshore
| operator = [[Total S.A.]]
| operator = [[Total S.A.]]
| partners =[[Total S.A.]]<br/>[[Eni]]<br/>[[BG Group]]<br/>[[E.ON]]<br/>[[ExxonMobil]]<br/>[[Chevron Corporation]]<br/>[[Dyas]]<br/>[[Oranje-Nassau Energie]]
| partners =[[Total S.A.]]<br />[[Eni]]<br />[[BG Group]]<br />[[Premier Oil]]<br />[[ExxonMobil]]<br />[[Chevron Corporation]]<br />[[Dyas]]<br />[[Oranje-Nassau Energie]]
| contractors =
| contractors =
| discovery = 1985 (Franklin)<br/>1991 (Elgin)
| discovery = 1985 (Franklin)<br />1991 (Elgin)
| start_development =
| start_development =
| start_production = March 2001 (Elgin)<br/>August 2001 (Franklin)
| start_production = March 2001 (Elgin)<br />August 2001 (Franklin)
| peak_year =
| peak_year =
| abandonment =
| abandonment =
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| formations = Upper Jurassic Fulmar Formation (Franklin Sand)
| 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]] {{convert|240|km|nmi}} east of [[Aberdeen]], [[Scotland]] at a water depth of {{convert|93|m}}. 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.
The '''Elgin–Franklin fields''' are two adjacent [[gas condensate]] fields located in the Central Graben Area of the [[North Sea]] {{convert|240|km|nmi}} east of [[Aberdeen]], [[Scotland]] at a water depth of {{convert|93|m}}. 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.


==History==
==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.<ref name = "Fort" /> The field was named after British Explorer Sir [[John Franklin]], and first production was in August 2001.<ref name = EFfacts>
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.<ref name = "Fort" /> The field was named after British Explorer Sir [[John Franklin]], and first production was in August 2001.<ref name = EFfacts>{{cite web
{{cite web
| title=ELGIN / FRANKLIN FACTS & FIGURES
| title=ELGIN / FRANKLIN FACTS & FIGURES
| url=http://www.uk.total.com/activities/elgin_franklin_facts.asp#elginfield|publisher=Total
| url=http://www.uk.total.com/activities/elgin_franklin_facts.asp#elginfield
| publisher=Total
| accessdate=1 January 2014
| accessdate=1 January 2014
| archive-url=https://web.archive.org/web/20120330233445/http://www.uk.total.com/activities/elgin_franklin_facts.asp#elginfield
}}
| archive-date=30 March 2012
⚫
</ref>
| url-status=dead
⚫
}}</ref>


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, Moray|Elgin]]. Production from the Elgin field began in March 2001.<ref name = EFfacts />
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, Moray|Elgin]]. It is also named as a tribute to a geologist named Nigel who was instrumental in the field's discovery, Elgin is an [[anagram]] of Nigel.<ref>{{Cite web|url=http://www.snsbi.org.uk/Nomina_articles/Nomina_32_Young.pdf|title=Oil and Gas field names in the North Sea}}</ref> Production from the Elgin field began in March 2001.<ref name = EFfacts />


The Glenelg satellite field was discovered in 1999 by well 29/4d-4, drilled by Total.<ref name=G_facts>
The Glenelg satellite field was discovered in 1999 by well 29/4d-4, drilled by Total.<ref name=G_facts>{{cite web
{{cite web
| title=Glenelg Fact Sheet
| title=Glenelg Fact Sheet
| url=http://www.uk.total.com/pdf/activities/Glenelg.pdf|publisher=Total
| url=http://www.uk.total.com/pdf/activities/Glenelg.pdf
| publisher=Total
| accessdate=1 January 2014
| accessdate=1 January 2014
| archive-url=https://web.archive.org/web/20140101145918/http://www.uk.total.com/pdf/activities/Glenelg.pdf
}}
| archive-date=1 January 2014
⚫
</ref> 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.<ref name=Glenelg>
| url-status=dead
{{cite web
⚫
}}</ref> 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.<ref name=Glenelg>{{cite web
| title=Glenelg
| title=Glenelg
| url=http://www.uk.total.com/activities/glenelg.asp|publisher=Total
| url=http://www.uk.total.com/activities/glenelg.asp
| publisher=Total
| accessdate=1 January 2014
| accessdate=1 January 2014
| archive-url=https://web.archive.org/web/20140108162634/http://uk.total.com/activities/glenelg.asp
}}
| archive-date=8 January 2014
⚫
</ref>
| url-status=dead
⚫
}}</ref>


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.<ref name=W_F>
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.<ref name=W_F>{{cite web
{{cite web
| title=West Franklin
| title=West Franklin
| url=http://www.uk.total.com/activities/west_franklin.asp
| url=http://www.uk.total.com/activities/west_franklin.asp
| publisher=Total
| publisher=Total
| accessdate=1 January 2014
| accessdate=1 January 2014
| archive-url=https://web.archive.org/web/20180806131550/http://www.uk.total.com/activities/west_franklin.asp
}}
| archive-date=6 August 2018
⚫
</ref>. A new wellhead platform was installed on West Franklin in 2014 with three wells being drilled as of 2016. Production from the first well (29/5b-H1Z) staered in 2015 <ref>http://www.total.com/en/media/news/press-releases/uk-west-franklin-phase-2-brought-stream-north-sea</ref>. A second wellhead platform Elgin B has also been installed at Elgin and is bridge linked to the Elgin A platform and PUQ to enable extra infill production wells to be drilled.
| url-status=dead
⚫
}}</ref> A new wellhead platform was installed on West Franklin in 2014 with three wells being drilled as of 2016. Production from the first well (29/5b-H1Z) started in 2015.<ref>{{Cite web|url=http://www.total.com/en/media/news/press-releases/uk-west-franklin-phase-2-brought-stream-north-sea|title = UK: West Franklin Phase 2 brought on stream in the North Sea| date=15 January 2015 }}</ref> A second wellhead platform Elgin B has also been installed at Elgin and is bridge linked to the Elgin A platform and PUQ to enable extra infill production wells to be drilled.


===March 2012 gas leak===
===March 2012 gas leak===
Line 84: Line 95:
| first=Emily
| first=Emily
| title=Total admits it could take six months to stop gas leak
| title=Total admits it could take six months to stop gas leak
| url=http://www.telegraph.co.uk/finance/newsbysector/energy/oilandgas/9168645/Total-admits-it-could-take-six-months-to-stop-gas-leak.html
| url=https://www.telegraph.co.uk/finance/newsbysector/energy/oilandgas/9168645/Total-admits-it-could-take-six-months-to-stop-gas-leak.html
| accessdate=1 January 2014
| accessdate=1 January 2014
| newspaper=The Telegraph
| newspaper=The Telegraph
| date=27 March 2012
| date=27 March 2012
}}</ref> No injuries were reported and 219&nbsp;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&nbsp;personnel were evacuated later on the same day.<ref>{{cite web|last=Schaps|first=Karolin|title=Total shuts Elgin gas, oil output after leak|url=http://uk.reuters.com/article/2012/03/26/uk-britain-franklin-leak-idUKBRE82P06W20120326|publisher=Reuters|accessdate=30 December 2013|date=26 March 2012}}</ref>
}}</ref> No injuries were reported and 219&nbsp;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.<ref>{{cite web|last=Schaps|first=Karolin|title=Total shuts Elgin gas, oil output after leak|url=http://uk.reuters.com/article/uk-britain-franklin-leak-idUKBRE82P06W20120326|archive-url=https://web.archive.org/web/20160305202915/http://uk.reuters.com/article/uk-britain-franklin-leak-idUKBRE82P06W20120326|url-status=dead|archive-date=March 5, 2016|publisher=Reuters|accessdate=30 December 2013|date=26 March 2012}}</ref>


At the time of the incident the fields were producing {{convert|120000|oilbbl/d}} of oil equivalent, about 7% of the UK's gas production.<ref>{{cite web|last=Kavanagh|first=Michael|title=Total resumes Elgin-Franklin production|url=http://www.ft.com/cms/s/0/d0e5e510-8819-11e2-b011-00144feabdc0.html#axzz2oycLuJHO|publisher=Financial Times|accessdate=30 December 2013|date=11 March 2013}}</ref> 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 {{convert|6|nmi}} in length. The [[HM Coastguard]] declared a {{convert|2|nmi}} exclusion zone for ships and a {{convert|3|mi}} exclusion zone for aircraft. Shell E&P also evacuated non essential staff from the separate Shearwater platform located in block 22/30b {{convert|6|km|nmi|abbr=on}} from Elgin.<ref>
At the time of the incident the fields were producing {{convert|120000|oilbbl/d}} of oil equivalent, about 7% of the UK's gas production.<ref>{{cite web|last=Kavanagh|first=Michael|title=Total resumes Elgin-Franklin production|url=http://www.ft.com/cms/s/0/d0e5e510-8819-11e2-b011-00144feabdc0.html#axzz2oycLuJHO|publisher=Financial Times|accessdate=30 December 2013|date=11 March 2013}}</ref> 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 {{convert|6|nmi}} in length. The [[HM Coastguard]] declared a {{convert|2|nmi}} exclusion zone for ships and a {{convert|3|mi}} exclusion zone for aircraft. Shell E&P also evacuated non essential staff from the separate Shearwater platform located in block 22/30b {{convert|6|km|nmi|abbr=on}} from Elgin.<ref>
Line 97: Line 108:
| work = BBC
| work = BBC
| accessdate = 2012-03-31
| accessdate = 2012-03-31
| url = http://www.bbc.co.uk/news/uk-scotland-north-east-orkney-shetland-17522086
| url = https://www.bbc.co.uk/news/uk-scotland-north-east-orkney-shetland-17522086
}}</ref> At its peak, {{convert|200000|m3/d}} of gas was being released, which slowed when a [[relief well]] was drilled. The platform [[Gas flare|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.<ref name = guardian>{{cite news|title=Elgin North Sea gas platform resumes production almost year after leak|url=https://www.theguardian.com/business/2013/mar/11/elgin-north-sea-gas-platform-reopens|accessdate=30 December 2013|newspaper=The Guardian|date=11 March 2013}}</ref>
}}</ref> At its peak, {{convert|200000|m3/d}} of gas was being released, which slowed when a [[relief well]] was drilled. The platform [[Gas flare|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.<ref name = guardian>{{cite news|title=Elgin North Sea gas platform resumes production almost year after leak|url=https://www.theguardian.com/business/2013/mar/11/elgin-north-sea-gas-platform-reopens|accessdate=30 December 2013|newspaper=The Guardian|date=11 March 2013}}</ref>


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 (stratigraphy)|formation]] above the producing reservoir.<ref>{{cite web|last=Patel|first=Tara|title=Total’s Elgin-Franklin Field Producing at Half Pre-Accident Rate|url=http://www.bloomberg.com/news/2013-04-24/total-s-elgin-franklin-field-producing-at-half-pre-accident-rate.html|publisher=Bloomberg|accessdate=30 December 2013}}</ref> Total identified the origin of the gas leak to be an unexploited [[chalk]] reservoir layer of the Hod formation located at a depth of {{convert|4500|m}}, above the [[Petroleum reservoir|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 [[Casing (borehole)|steel casing]] during [[Boring (earth)|drilling]] in 1997. On 25 February 2012 an increase in pressure was observed in the C [[Annulus (oil well)|annulus]] within the [[Oil well|well]] and remedial operations started on 4 March 2012. Total believe that the C annulus failed and gas was observed leaking from the {{convert|30|in|adj=on}} conductor.<ref>{{cite web|url=http://www.elgin.total.com/Elgin/content/documents/elgin_gas_leak_press_conference_aberdeen.pdf |title=Elgin Gas Leak : Press Conference : Aberdeen, 30 March 2012?? |publisher=Elgin.total.com |accessdate=2013-10-25}}</ref>
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 (stratigraphy)|formation]] above the producing reservoir.<ref>{{cite news|last=Patel|first=Tara|title=Total's Elgin-Franklin Field Producing at Half Pre-Accident Rate|newspaper=Bloomberg.com|date=24 April 2013|url=https://www.bloomberg.com/news/2013-04-24/total-s-elgin-franklin-field-producing-at-half-pre-accident-rate.html|publisher=Bloomberg|accessdate=30 December 2013}}</ref> Total identified the origin of the gas leak to be an unexploited [[chalk]] reservoir layer of the Hod formation located at a depth of {{convert|4500|m}}, above the [[Petroleum reservoir|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 [[Casing (borehole)|steel casing]] during [[Boring (earth)|drilling]] in 1997.


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.<ref>{{cite web|url=http://www.bbc.co.uk/news/uk-scotland-north-east-orkney-shetland-17621879 |title=BBC News - Total gas leak: Team assesses leak at Elgin platform in North Sea |publisher=Bbc.co.uk |date=2012-04-05 |accessdate=2013-10-25}}</ref>
On 25 February 2012, an increase in pressure was observed in the C [[Annulus (oil well)|annulus]] within the [[Oil well|well]] and remedial operations started on 4 March 2012. Total believe that the C annulus failed and gas was observed leaking from the {{convert|30|in|adj=on}} conductor.<ref>{{cite web|url=http://www.elgin.total.com/Elgin/content/documents/elgin_gas_leak_press_conference_aberdeen.pdf |title=Elgin Gas Leak : Press Conference : Aberdeen, 30 March 2012?? |date=11 March 2013 |publisher=Elgin.total.com |accessdate=2013-10-25}}</ref>


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.<ref>{{cite web|url=https://www.bbc.co.uk/news/uk-scotland-north-east-orkney-shetland-17621879 |title=BBC News - Total gas leak: Team assesses leak at Elgin platform in North Sea |publisher=Bbc.co.uk |date=2012-04-05 |accessdate=2013-10-25}}</ref>
During April 2012 a diverter assembly was installed around the G4 well head to divert the leaking gas (estimated then at {{convert|200000|m3/d}}) away from the platform in a controlled manner enabling well control operations to begin.<ref>{{cite web|url=http://www.elgin.total.com/elgin/pressrelease.aspx?contentid=824 |title=Total &#124; Elgin gas leak: weekly summary (April 20-26) |publisher=Elgin.total.com |date=2012-03-25 |accessdate=2013-10-25}}</ref> 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 {{convert|50000|m3/d}}.<ref>{{cite web|url=http://www.elgin.total.com/elgin/pressrelease.aspx?contentid=850 |title=Total &#124; Elgin gas leak : Weekly Update (May 4 - 10) |publisher=Elgin.total.com |date=2012-03-25 |accessdate=2013-10-25}}</ref>
During April 2012 a diverter assembly was installed around the G4 well head to divert the leaking gas (estimated then at {{convert|200000|m3/d}}) away from the platform in a controlled manner enabling well control operations to begin.<ref>{{cite web|url=http://www.elgin.total.com/elgin/pressrelease.aspx?contentid=824 |title=Total &#124; Elgin gas leak: weekly summary (April 20–26) |publisher=Elgin.total.com |date=2012-03-25 |accessdate=2013-10-25}}</ref> 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.


On 16 May Total announced that the leak had been stopped.<ref>{{cite web|url=http://www.elgin.total.com/elgin/pressrelease.aspx?contentid=854 |title=Total &#124; Elgin leak stopped after well intervention |publisher=Elgin.total.com |date=2012-03-25 |accessdate=2013-10-25}}</ref>
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 {{convert|50000|m3/d}}.<ref>{{cite web|url=http://www.elgin.total.com/elgin/pressrelease.aspx?contentid=850 |title=Total &#124; Elgin gas leak : Weekly Update (May 4–10) |publisher=Elgin.total.com |date=2012-03-25 |accessdate=2013-10-25}}</ref>

On 16 May, Total announced that the leak had been stopped.<ref>{{cite web|url=http://www.elgin.total.com/elgin/pressrelease.aspx?contentid=854 |title=Total &#124; Elgin leak stopped after well intervention |publisher=Elgin.total.com |date=2012-03-25 |accessdate=2013-10-25}}</ref>


Production restarted on 9 March 2013.
Production restarted on 9 March 2013.

===December 2016 Helicopter Incident===

On 28 December 2016 a [[Sikorsky S-92]] helicopter (registration G-WNSR, serial number 920250<ref name="CAA WNSR">{{cite web |url=https://publicapps.caa.co.uk/modalapplication.aspx?catid=1&pagetype=65&appid=1&mode=detailnosummary&fullregmark=WNSR |title=GINFO Search Results |publisher=[[Civil Aviation Authority (United Kingdom)]] |date=9 January 2017 |accessdate=10 January 2017 }}</ref>) operated by [[CHC Helicopter]] experienced "unexpected control responses" whilst in mid-air on a routine shuttle flight between two oil installations in the [[North Sea]]. The pilots conducted an emergency landing on the West Franklin platform.<ref name="EnVo1">{{cite news |last=Burns |first=Niamh |url=https://www.energyvoice.com/other-news/127827/helicopter-spun-platform-deck-emergency-landing/ |title=Helicopter 'spun on platform deck' in emergency landing |work=Energy Voice |publisher=[[DC Thomson]] |date=30 December 2016 |accessdate=10 January 2017 }}</ref> The helicopter is reported to have spun on the helideck during the landing, damaging the helicopter wheels and rotor blades.<ref name="EnVo2">{{cite news |last=Lammey |first=Mark |url=https://www.energyvoice.com/oilandgas/north-sea/128044/fresh-pictures-emerge-showing-aftermath-of-north-sea-helicopter-emergency-landing/ |title=Fresh pictures emerge showing aftermath of North Sea helicopter emergency landing |work=Energy Voice |publisher=[[DC Thomson]] |date=5 January 2017 |accessdate=10 January 2017 }}</ref> The helideck also sustained damage during the emergency landing.<ref name="EnVo2" /> There were no reported injuries amongst the nine passengers and two crew during the incident.<ref name="EnVo1" /> The aircraft was transported back to Aberdeen via ship, at which time the [[Air Accidents Investigation Branch]] began their investigation into the incident.<ref name="BBC Jan 17-1">{{cite news |url=https://www.bbc.co.uk/news/uk-scotland-north-east-orkney-shetland-38521817 |title=North Sea helicopter 'gouged platform deck' |work=BBC News |publisher=[[BBC]] |date=5 January 2017 |accessdate=10 January 2017 }}</ref>

Sikorsky issued a notice on 9 January 2017 grounding all S-92 aircraft until the tail rotors have been inspected. The inspection work takes approximately 11 man hours to complete.<ref name="BBC Jan 17-2">{{cite news |url=https://www.bbc.co.uk/news/uk-scotland-north-east-orkney-shetland-38568615 |title=Sikorsky grounds S92 helicopters for safety checks after incident |work=BBC News |publisher=[[BBC]] |date=10 January 2017 |accessdate=10 January 2017 }}</ref> The Air Accidents Investigation Branch issued an update on 11 January 2017 which reported that the tail rotor pitch change shaft bearing had seized. The bearing showed signs of severe overheating and significant wear. The failure of the bearing allowed the tail rotor driveshaft to damage the tail rotor servo. The damage to the tail rotor servo is considered to be the cause of tail rotor control. The [[health and usage monitoring systems]] had discovered the flaw the day before flight, but the maintenance crew had not.<ref name="AAIB S1 2017">{{cite web |url=https://assets.publishing.service.gov.uk/media/587640a9ed915d0aeb00013f/AAIB_S1-2017_G-WNSR.pdf |title=AAIB Bulletin S1/2017 SPECIAL |publisher=[[Air Accidents Investigation Branch]] |date=11 January 2017 |accessdate=12 January 2017 }}</ref>


==Ownership==
==Ownership==
Line 123: Line 142:
! Company !! Equity!! Note
! Company !! Equity!! Note
|-
|-
| Total || 35.784% || Operator (formerly Elf) held via EFOG joint venture
| Total E&P UK Ltd. || 46.137% || Operator (formerly Elf)
|-
|-
| Eni || 21.867% ||
| Eni Elgin/Franklin Ltd. || 21.867% ||
|-
|-
| BG Group || 14.110 %||
| Harbour Energy Ltd. || 14.110 %|| formerly Chrysaor Ltd.
|-
|-
|GDF Suez || 10.389% || held via EFOG joint venture
| Harbour Energy Ltd. || 5.200% || formerly Premier Oil UK Ltd.
|-
|-
|E.ON Ruhrgas || 5.200% ||
| Esso E&P UK Ltd. || 4.375% ||
|-
|-
| Exxon Mobil || 4.375% ||
| Chevron North Sea Ltd. || 3.900% || formerly Texaco
|-
|-
|Chevron || 3.900% || formerly Texaco
| One-Dyas E&P Ltd. || 2.1875% ||
|-
|-
|Dyas UK Limited || 2.1875% ||
|Summit E&P Ltd. ||2.1875 % ||
|-
|Summit Exploration and Production 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===
===Glenelg===
Line 151: Line 167:
! Company !! Equity!! Note
! Company !! Equity!! Note
|-
|-
| Total || 49.47% || Operator (formerly Elf)
| Total E&P UK Ltd. || 58.73% || Operator (formerly Elf)
|-
|-
| E.ON Ruhrgas || 18.57 %||
| Harbour Energy Ltd. || 18.57 %|| formerly Premier Oil UK Ltd.
|-
|-
| BG Group || 14.70% ||
| Harbour Energy Ltd. || 14.70% || formerly Chrysaor Ltd
|-
|-
| GDF Suez || 9.26% ||
| Eni Elgin/Franklin Ltd. || 8.00% ||
|-
| Eni (UK) Limited || 8.00% ||
|}
|}


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===Franklin field===
===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 {{convert|5500|m}} depth. It is at pressures of {{convert|14000|psi|abbr=on}} and temperatures of {{convert|190|C}}. Originally the recoverable reserves for Franklin were estimated at {{convert|820|e9cuft|abbr=off}} of natural gas and {{convert|120|Moilbbl}} of [[natural-gas condensate|condensate]].<ref name=pgc>
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|Pentland formation]] forms a second reservoir with a separate hydrocarbon pool. The reservoir is at {{convert|5500|m}} depth. It is at pressures of {{convert|14000|psi|abbr=on}} and temperatures of {{convert|190|C}}. Originally the recoverable reserves for Franklin were estimated at {{convert|820|e9cuft|abbr=off}} of natural gas and {{convert|120|Moilbbl}} of [[natural-gas condensate|condensate]].<ref name=pgc>
{{cite journal
{{cite book
| last=Lasocki
| last=Lasocki
| first=J |author2=Guemene, J M |author3=Hedayati, A |author4=Legorjus, C |author5=Page, W M
| first=J |author2=Guemene, J M |author3=Hedayati, A |author4=Legorjus, C |author5=Page, W M
| title=The Elgin and Franklin fields: UK Blocks 22/30c, 22/30b and 29/5b
| chapter=The Elgin and Franklin fields: UK Blocks 22/30c, 22/30b and 29/5b
| title=Petroleum Geology of Northwest Europe: Proceedings of the 5th Conference
| journal=Geological Society, London
| publisher=Geological Society, London
| year=1999
| year=1999
| volume=5
| volume=5
Line 177: Line 192:
| pages=1007–1020
| pages=1007–1020
| doi=10.1144/0051007
| doi=10.1144/0051007
| url=http://pgc.lyellcollection.org/content/5/1007.abstract
| chapter-url=http://pgc.lyellcollection.org/content/5/1007.abstract
| accessdate=1 January 2014
| accessdate=1 January 2014
}}
}}
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===Elgin field===
===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 {{convert|890|e9cuft|abbr=off}} of gas and {{convert|245|Moilbbl}} of condensate.<ref name=pgc/>
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 recoverable reserves for Elgin was {{convert|890|e9cuft|abbr=off}} of gas and {{convert|245|Moilbbl}} of condensate.<ref name=pgc/>


===West Franklin===
===West Franklin===
Line 194: Line 209:
==Development==
==Development==


The Elgin-Franklin development is located in the Central Graben Area of the [[North Sea]] {{convert|240|km|nmi}} east of [[Aberdeen]], [[Scotland]] at a water depth of {{convert|93|m}}. The installation consists of three separate platforms, two of which are connected by a {{convert|90|m|ft|abbr=on}} 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, Highland|Nigg]], Scotland, and installed in July 2000. The facility has a processing capacity of {{convert|516|e6cuft/d}} of gas and {{convert|175|koilbbl/d}} of condensate.<ref name = elginPUQ >
The Elgin-Franklin development is located in the Central Graben Area of the [[North Sea]] {{convert|240|km|nmi}} east of [[Aberdeen]], [[Scotland]] at a water depth of {{convert|93|m}}. The installation consists of three separate platforms, two of which are connected by a {{convert|90|m|ft|abbr=on}} 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, Highland|Nigg]], Scotland, and installed in July 2000. The facility has a processing capacity of {{convert|516|e6cuft/d}} of gas and {{convert|175|koilbbl/d}} of condensate.<ref name="elginPUQ">{{cite web
{{cite web
| title=Total ICOP, Elgin PUQ
| title=Total ICOP, Elgin PUQ
| url=http://www.total-icop.co.uk/elgin_franklin/elgin_puq.asp
| url=http://www.total-icop.co.uk/elgin_franklin/elgin_puq.asp
| publisher=Total
| publisher=Total
|accessdate=1 January 2014
| accessdate=1 January 2014
| archive-url=https://web.archive.org/web/20140101210554/http://www.total-icop.co.uk/elgin_franklin/elgin_puq.asp
| archive-date=1 January 2014
| url-status=dead
}}</ref>
}}</ref>
The Franklin wellhead platform has nine well slots. It is not normally manned but has a helideck and shelter for up to 20&nbsp;people. The Elgin wellhead platform has 12&nbsp;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 Franklin wellhead platform (WHP) has nine well slots (seven wells on the Franklin Field and two extended reach wells on West Franklin) . It is not normally manned but has a helideck and shelter for up to 20&nbsp;people. The Elgin wellhead platform has 12 well slots (11 wells on Elgin and one extended reach well on Glenelg). 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 west Franklin and Elgin B platforms were installed in 2014 in order to enable drilling of further development wells in the fields due to constraints in the existing facilities. In 2017 there were three wells on West Franklin and three wells on Elgin B)


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]].
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]].
Line 246: Line 267:
}}
}}
*{{Citation
*{{Citation
| last = Total
|last = Total
| date = 2004
|date = 2004
| title = Elgin/Franklin information brochure
|title = Elgin/Franklin information brochure
| publisher = Total E&P UK Plc
|publisher = Total E&P UK Plc
| accessdate = 2012-04-07
|accessdate = 2012-04-07
| url = http://www.uk.total.com/pdf/Library/PUBLICATIONS/Library-ElginFranklinBrochure.pdf
|url = http://www.uk.total.com/pdf/Library/PUBLICATIONS/Library-ElginFranklinBrochure.pdf
|url-status = dead
|archiveurl = https://web.archive.org/web/20120807095518/http://www.uk.total.com/pdf/Library/PUBLICATIONS/Library-ElginFranklinBrochure.pdf
⚫
|archivedate = 2012-08-07
}}
}}
* {{cite web
* {{cite web
Line 260: Line 284:
| accessdate = 2012-03-31
| accessdate = 2012-03-31
| url = http://www.total-icop.co.uk/elgin_franklin/elgin_franklin.asp
| url = http://www.total-icop.co.uk/elgin_franklin/elgin_franklin.asp
⚫
| archive-date = 2012-04-01
| archive-url = https://web.archive.org/web/20120401230243/http://www.total-icop.co.uk/elgin_franklin/elgin_franklin.asp
| url-status = dead
}}
}}
* {{cite web
* {{cite web
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| date = 2012-03-31
| date = 2012-03-31
| url = http://www.uk.total.com/activities/elgin_franklin.asp
| url = http://www.uk.total.com/activities/elgin_franklin.asp
| archive-url = https://web.archive.org/web/20180806131550/http://www.uk.total.com/activities/elgin_franklin.asp
| archive-date = 2018-08-06
| url-status = dead
}}
}}
* {{Cite news
* {{Cite news
Line 275: Line 305:
| work = BBC
| work = BBC
| accessdate = 2012-03-31
| accessdate = 2012-03-31
| url = http://www.bbc.co.uk/news/uk-scotland-north-east-orkney-shetland-17522086
| url = https://www.bbc.co.uk/news/uk-scotland-north-east-orkney-shetland-17522086
}}
}}
* {{Cite journal
* {{Cite journal
Line 281: Line 311:
| first = J.-L.
| first = J.-L.
| date = 2011
| date = 2011
| title = Advanced drilling in HP/HT: Total’s experience on Elgin/Franklin (UK North Sea)
| title = Advanced drilling in HP/HT: Total's experience on Elgin/Franklin (UK North Sea)
| journal = Journal of Petroleum Technology
| journal = Journal of Petroleum Technology
| volume = October
| volume = October
| issue = 10
| pages = 116–120
| pages = 116–120
| doi = 10.2118/129422-JPT
| accessdate = 2012-03-28
| accessdate = 2012-03-28
| url = http://www.spe.org/jpt/print/archives/2011/10/19TTS.pdf
| url = http://www.spe.org/jpt/print/archives/2011/10/19TTS.pdf
| archive-url = https://web.archive.org/web/20120405182922/http://www.spe.org/jpt/print/archives/2011/10/19TTS.pdf
| archive-date = 2012-04-05
| url-status = dead
}}
}}
* {{cite web
* {{cite web
Line 295: Line 330:
| accessdate = 2012-03-31
| accessdate = 2012-03-31
| url = http://diseaseclimate.blogspot.com/2012/03/humongous-gas-leak-in-north-sea.html
| url = http://diseaseclimate.blogspot.com/2012/03/humongous-gas-leak-in-north-sea.html
}}
*{{Cite news
| last = Osborne
| first = Lucy
⚫
| date = 2012-04-05
| title = Total gas leak: Greenpeace releases infra-red images of 'explosive' gas spewing from Elgin rig
| work = Mail Online
⚫
| accessdate = 2012-04-07
| url = http://www.dailymail.co.uk/sciencetech/article-2125471/Total-gas-leak-Greenpeace-release-infra-red-image-explosive-gas-spewing-Elgin-rig.html
}}
}}


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[[Category:North Sea energy]]
[[Category:North Sea energy]]
[[Category:Oil fields of Scotland]]
[[Category:Oil fields of Scotland]]
[[Category:Total S.A.]]
[[Category:TotalEnergies]]
[[Category:ExxonMobil oil and gas fields]]
[[Category:ExxonMobil oil and gas fields]]
[[Category:Eni]]
[[Category:Eni]]
[[Category:E.ON]]

Latest revision as of 19:56, 12 September 2024

Elgin–Franklin field
Elgin–Franklin fields is located in North Sea
Elgin–Franklin fields
Location of Elgin–Franklin field
CountryScotland, United Kingdom
LocationNorth Sea
Block22/30b
22/30c
29/5b
Offshore/onshoreOffshore
Coordinates57°10′N 2°00′E / 57.167°N 2.000°E / 57.167; 2.000
OperatorTotal S.A.
PartnersTotal S.A.
Eni
BG Group
Premier Oil
ExxonMobil
Chevron Corporation
Dyas
Oranje-Nassau Energie
Field history
Discovery1985 (Franklin)
1991 (Elgin)
Start of productionMarch 2001 (Elgin)
August 2001 (Franklin)
Production
Current production of oil45,000 barrels per day (~2.2×10^6 t/a)
Recoverable oil365 million barrels (~4.98×10^7 t)
Estimated gas in place1,710×10^9 cu ft (48×10^9 m3)
Producing formationsUpper 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.

History

[edit]

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. It is also named as a tribute to a geologist named Nigel who was instrumental in the field's discovery, Elgin is an anagram of Nigel.[3] 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.[4] 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.[5]

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.[6] A new wellhead platform was installed on West Franklin in 2014 with three wells being drilled as of 2016. Production from the first well (29/5b-H1Z) started in 2015.[7] A second wellhead platform Elgin B has also been installed at Elgin and is bridge linked to the Elgin A platform and PUQ to enable extra infill production wells to be drilled.

March 2012 gas leak

[edit]

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.[8] 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.[9]

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.[10] 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.[11] 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.[12]

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.[13] 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.[14]

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.[15]

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.[16] 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).[17]

On 16 May, Total announced that the leak had been stopped.[18]

Production restarted on 9 March 2013.

December 2016 Helicopter Incident

[edit]

On 28 December 2016 a Sikorsky S-92 helicopter (registration G-WNSR, serial number 920250[19]) operated by CHC Helicopter experienced "unexpected control responses" whilst in mid-air on a routine shuttle flight between two oil installations in the North Sea. The pilots conducted an emergency landing on the West Franklin platform.[20] The helicopter is reported to have spun on the helideck during the landing, damaging the helicopter wheels and rotor blades.[21] The helideck also sustained damage during the emergency landing.[21] There were no reported injuries amongst the nine passengers and two crew during the incident.[20] The aircraft was transported back to Aberdeen via ship, at which time the Air Accidents Investigation Branch began their investigation into the incident.[22]

Sikorsky issued a notice on 9 January 2017 grounding all S-92 aircraft until the tail rotors have been inspected. The inspection work takes approximately 11 man hours to complete.[23] The Air Accidents Investigation Branch issued an update on 11 January 2017 which reported that the tail rotor pitch change shaft bearing had seized. The bearing showed signs of severe overheating and significant wear. The failure of the bearing allowed the tail rotor driveshaft to damage the tail rotor servo. The damage to the tail rotor servo is considered to be the cause of tail rotor control. The health and usage monitoring systems had discovered the flaw the day before flight, but the maintenance crew had not.[24]

Ownership

[edit]

The fields are operated by Total E&P UK Limited, a subsidiary of Total S.A.(formerly Elf Aquitaine).

Elgin-Franklin and West Franklin

[edit]

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 E&P UK Ltd. 46.137% Operator (formerly Elf)
Eni Elgin/Franklin Ltd. 21.867%
Harbour Energy Ltd. 14.110 % formerly Chrysaor Ltd.
Harbour Energy Ltd. 5.200% formerly Premier Oil UK Ltd.
Esso E&P UK Ltd. 4.375%
Chevron North Sea Ltd. 3.900% formerly Texaco
One-Dyas E&P Ltd. 2.1875%
Summit E&P Ltd. 2.1875 %

Glenelg

[edit]

The partners in the Glenelg field are shown below.[5]

Company Equity Note
Total E&P UK Ltd. 58.73% Operator (formerly Elf)
Harbour Energy Ltd. 18.57 % formerly Premier Oil UK Ltd.
Harbour Energy Ltd. 14.70% formerly Chrysaor Ltd
Eni Elgin/Franklin Ltd. 8.00%

Geology

[edit]

Franklin field

[edit]

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 (19×10^6 m3) of condensate.[25]

Elgin field

[edit]

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 recoverable reserves for Elgin was 890 billion cubic feet (25 billion cubic metres) of gas and 245 million barrels (39.0×10^6 m3) of condensate.[25]

West Franklin

[edit]

The West Franklin structure has a Fulmar formation reservoir.

Glenelg

[edit]

The Glenelg field is a tilted fault block with a Fulmar formation reservoir.

Development

[edit]

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 (14.6×10^6 m3/d) of gas and 175 thousand barrels per day (27.8×10^3 m3/d) of condensate.[26]

The Franklin wellhead platform (WHP) has nine well slots (seven wells on the Franklin Field and two extended reach wells on West Franklin) . It is not normally manned but has a helideck and shelter for up to 20 people. The Elgin wellhead platform has 12 well slots (11 wells on Elgin and one extended reach well on Glenelg). 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 west Franklin and Elgin B platforms were installed in 2014 in order to enable drilling of further development wells in the fields due to constraints in the existing facilities. In 2017 there were three wells on West Franklin and three wells on Elgin B)

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

[edit]
  • 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

[edit]

References

[edit]
  1. ^ a b Fort, Joel (May 2000). "The Elgin/Franklin Project: Developing the Largest High Pressure/High Temperature Fields in the World". Offshore Technology Conference: 1. doi:10.4043/12117-MS. Retrieved 31 December 2013.
  2. ^ a b c "ELGIN / FRANKLIN FACTS & FIGURES". Total. Archived from the original on 30 March 2012. Retrieved 1 January 2014.
  3. ^ "Oil and Gas field names in the North Sea" (PDF).
  4. ^ "Glenelg Fact Sheet" (PDF). Total. Archived from the original (PDF) on 1 January 2014. Retrieved 1 January 2014.
  5. ^ a b "Glenelg". Total. Archived from the original on 8 January 2014. Retrieved 1 January 2014.
  6. ^ "West Franklin". Total. Archived from the original on 6 August 2018. Retrieved 1 January 2014.
  7. ^ "UK: West Franklin Phase 2 brought on stream in the North Sea". 15 January 2015.
  8. ^ Gosden, Emily (27 March 2012). "Total admits it could take six months to stop gas leak". The Telegraph. Retrieved 1 January 2014.
  9. ^ Schaps, Karolin (26 March 2012). "Total shuts Elgin gas, oil output after leak". Reuters. Archived from the original on March 5, 2016. Retrieved 30 December 2013.
  10. ^ Kavanagh, Michael (11 March 2013). "Total resumes Elgin-Franklin production". Financial Times. Retrieved 30 December 2013.
  11. ^ BBC News (2012-03-28). "Gas leak platform flare 'burning'". BBC. Retrieved 2012-03-31.
  12. ^ "Elgin North Sea gas platform resumes production almost year after leak". The Guardian. 11 March 2013. Retrieved 30 December 2013.
  13. ^ Patel, Tara (24 April 2013). "Total's Elgin-Franklin Field Producing at Half Pre-Accident Rate". Bloomberg.com. Bloomberg. Retrieved 30 December 2013.
  14. ^ "Elgin Gas Leak : Press Conference : Aberdeen, 30 March 2012??" (PDF). Elgin.total.com. 11 March 2013. Retrieved 2013-10-25.
  15. ^ "BBC News - Total gas leak: Team assesses leak at Elgin platform in North Sea". Bbc.co.uk. 2012-04-05. Retrieved 2013-10-25.
  16. ^ "Total | Elgin gas leak: weekly summary (April 20–26)". Elgin.total.com. 2012-03-25. Retrieved 2013-10-25.
  17. ^ "Total | Elgin gas leak : Weekly Update (May 4–10)". Elgin.total.com. 2012-03-25. Retrieved 2013-10-25.
  18. ^ "Total | Elgin leak stopped after well intervention". Elgin.total.com. 2012-03-25. Retrieved 2013-10-25.
  19. ^ "GINFO Search Results". Civil Aviation Authority (United Kingdom). 9 January 2017. Retrieved 10 January 2017.
  20. ^ a b Burns, Niamh (30 December 2016). "Helicopter 'spun on platform deck' in emergency landing". Energy Voice. DC Thomson. Retrieved 10 January 2017.
  21. ^ a b Lammey, Mark (5 January 2017). "Fresh pictures emerge showing aftermath of North Sea helicopter emergency landing". Energy Voice. DC Thomson. Retrieved 10 January 2017.
  22. ^ "North Sea helicopter 'gouged platform deck'". BBC News. BBC. 5 January 2017. Retrieved 10 January 2017.
  23. ^ "Sikorsky grounds S92 helicopters for safety checks after incident". BBC News. BBC. 10 January 2017. Retrieved 10 January 2017.
  24. ^ "AAIB Bulletin S1/2017 SPECIAL" (PDF). Air Accidents Investigation Branch. 11 January 2017. Retrieved 12 January 2017.
  25. ^ a b Lasocki, J; Guemene, J M; Hedayati, A; Legorjus, C; Page, W M (1999). "The Elgin and Franklin fields: UK Blocks 22/30c, 22/30b and 29/5b". Petroleum Geology of Northwest Europe: Proceedings of the 5th Conference. Petroleum Geology Conference Series. Vol. 5. Geological Society, London. pp. 1007–1020. doi:10.1144/0051007. Retrieved 1 January 2014.
  26. ^ "Total ICOP, Elgin PUQ". Total. Archived from the original on 1 January 2014. Retrieved 1 January 2014.
[edit]
Retrieved from "https://en.wikipedia.org/enwiki/w/index.php?title=Elgin–Franklin_fields&oldid=1245398756"