30:
563:. The decommissioning process, which requires regulatory approvals, is expected to cost about £400 million. Dunlin has been cited as an example of the impact a decommissioning decision has impacting surrounding infrastructure as per the 2014 Wood MER (Maximising Economic Recovery) Report - the "Domino Effect". Enquest will have to provide a pipeline "bypass" to allow continued export from the Thistle complex of fields to be exported via the 16" export line into the 24" line that runs from Dunlin to Cormorant Alpha.
503:
37:
535:
flowlines from Merlin comprise 8" water injection and production lines. These tie into the Osprey riser system at Dunlin. Merlin subsea controls tie in via a crossover manifold adjacent to Dunlin into the Osprey umbilical system. Flexible flowlines were installed for water injection service on Merlin and Osprey in 2002.
534:
The Merlin field was discovered in 1998 and was initially developed as a low cost CRINE field (Cost
Reduction In the New Era) utilising the discovery well recompleted as a subsea producer. The Merlin drill centre was progressively expanded to 3 subsea production wells and a single water injector. The
466:
The topsides facilities included capability to drill, produce, meter and export oil. It also has capability to re-inject water to maintain reservoir pressure, (111,250 bls/day) predicted. Peak production was 115,000 barrels per day in 1979; and it was approximately in the region of 3500 - 4000 bpd in
546:
Fairfield installed a 4" fuel gas import line from the
Thistle platform in 2012 to provide fuel for the platform power generation plant. The field had become gas deficient (insufficient associated gas being produced as a by product of oil production) under Shell. In an attempt to mitigate this Shell
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Osprey was developed by Shell in 1989/90 and employs two drill centres, one for production (with 8 subsea trees) and one for water injection (with 4 subsea trees). The drill centres are connected to the platform via two back to back flowline bundles containing 2 off 8" production flowlines and a 10"
550:
Dunlin acts as a pipeline node on the Brent system and provides connection point for the 16" export line from the
Enquest operated Thistle and Don Fields and the 16" line from the Murchison field (the latter in the process of being decommissioned by Canadian Natural Resources International - CNRI -
547:
had installed a 33KVa power import cable between Dunlin and Brent C in 2002. The Brent sequence fields rely on water injection to maintain production and Dunlin had an installed water injection plant capable of delivering 250,000 bwpd supplied by 5 electrically powered water injection pumps.
203:
The Field was originally discovered in July 1973 in a water depth of 151 metres (495 ft) approximately 12 km from the UK-Norway median line. Estimated recovery is 363 million barrels of oil. The oil reservoir is located at a depth of 9,000 feet (2,740 metres).
463:(229,000 tonnes) and it is designed to carry a topsides weight of 15,635 long tons (15,886 tonnes). The storage system was decommissioned by Shell from 2005 to 2007 prior to the sale to Fairfield Energy.
566:
The decommissioning of the
Murchison field and the Dunlin complex removes two "shippers" from the Brent system resulting in increase pipeline operating costs for the remaining users.
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water injection line. Subsea trees and the manifolds were supplied by
Cameron Oil Tools (now OneSubsea). Subsea control system was supplied by Kvaerner FSSL (now Aker solutions).
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type (Anglo Dutch
Offshore Concrete) and was installed in June 1977. It has four legs and storage capacity for 838,200 barrels of oil. The total sub-structure weight is 225,000
605:
293:
The field was developed by a single integrated drilling, production, storage and accommodation platform. The principal design data of the Dunlin platform was as follows:
644:
196:
Under
Fairfield initially the platform was operated using the duty holder model. Amec (now Worley) were the duty holder contractor and
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609:
90:
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Production started in August 1978 from the Dunlin Alpha platform. This platform is a concrete gravity base (GBS) structure of the
29:
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The oil production profile for Dunlin (in 1000s barrels per year) in the early operating period is shown in the graph:
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at a depth of 8,700 to 9,700 feet (2,652 to 2,957 m). The reservoir and its fluids had the following characteristics:
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2015 prior to the shut in announcement (Production ceased on 15 June 2015) Oil production is by pipeline to
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In May 2015, Fairfield Energy has announced plans to decommission its Dunlin Alpha platform in the
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was the engineering and upgrade project contract. Fairfield became the duty holder in April 2014.
484:
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Dunlin acts as the host platform for production from the Osprey and Merlin subsea fields.
8:
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Osprey and Merlin produce from the same Brent sequence geology as the main Dunlin Field.
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190:
511:
606:"Access to Fairfield Energy's Oil and Gas Infrastructure | Fairfield Energy"
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but was sold in 2008 and is now operated by
Fairfield Energy and partners MCX.
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Graphs are unavailable due to technical issues. There is more info on
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189:, in block number 211/23a and 211/24a. It was originally operated by
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645:"Low Oil Price Domino Effect to Shut More North Sea Fields Early"
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589:
594:. Ledbury: Oilfield Publications Limited. pp. 158–62.
631:"Fairfield Energy in move to decommission oil platform"
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345:Drilling, production, storage, accommodation
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329:Ewbank & Partners / Halcrow Offshore
282:310 million barrels, 52.2 million tonnes
441:Cormorant A 35 km 24-inch pipeline
36:
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590:Oilfield Publications Limited (1985).
398:Throughput oil, barrels per day (bpd)
177:is situated 195 km northeast of
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215:The reservoir comprises a middle
675:Oil and gas industry in Shetland
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35:
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266:250 standard cubic feet/barrel
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1:
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592:The North Sea Platform Guide
297:Dunlin platform design data
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44:Location of Dunlin oil field
7:
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449:Used on board as fuel gas
382:Storage capacity, barrels
318:Fabrication substructure
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633:. BBC News. 11 May 2015.
483:. Associated gas powers
226:Dunlin reservoir fluids
542:Pipeline Infrastructure
526:Subsea Satellite Fields
334:Topside weight, tonnes
321:Maasvlakte Netherlands
670:Oil fields of Scotland
430:Water injection start
305:61°16’30”N 01°35’51”E
485:electrical generation
406:Water injection, bpd
350:Accommodation (crew)
279:Recoverable reserves
665:North Sea oil fields
310:Water depth, metres
164:Producing formations
106:61.27500°N 1.59750°E
414:Platform installed
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151:Start of production
102: /
446:Gas production to
438:Oil production to
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64:northern North Sea
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422:Production start
361:Concrete gravity
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111:61.27500; 1.59750
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608:. Archived from
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326:Topsides design
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77:Offshore/onshore
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19:Dunlin oil field
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555:Decommissioning
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487:. Some gas was
469:Cormorant Alpha
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271:Sulfur content
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175:Dunlin oilfield
167:Middle Jurassic
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69:Location/blocks
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198:Aker Solutions
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612:on 2015-07-17
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250:100-1,500 md
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247:Permeability
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138:Field history
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614:. Retrieved
610:the original
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475:pipeline to
473:Brent System
471:and then by
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425:August 1978
302:Coordinates
292:
255:API gravity
214:
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551:June 2015)
512:Phabricator
390:Well slots
274:0.4 %
109: /
85:Coordinates
659:Categories
616:2015-07-16
570:References
477:Sullom Voe
417:June 1977
289:Production
242:24 %
231:Parameter
159:Production
94:61°16′30″N
561:North Sea
461:long tons
433:May 1979
342:Function
239:Porosity
220:sandstone
211:The field
143:Discovery
122:Operators
97:1°35′51″E
481:Shetland
409:111,250
401:150,000
385:800,000
217:Jurassic
187:Scotland
183:Shetland
133:see text
125:see text
80:Offshore
514:and on
337:17,450
258:36°API
179:Lerwick
53:Country
489:flared
374:Cells
234:Value
61:Region
457:ANDOC
366:Legs
358:Type
191:Shell
130:Owner
353:183
313:151
173:The
154:1978
146:1973
393:48
377:81
661::
578:^
491:.
479:,
369:4
185:,
181:,
647:.
619:.
518:.
Text is available under the Creative Commons Attribution-ShareAlike License. Additional terms may apply.
