The Forties Field, Blocks 21/10 and 22/6a, UK North Sea

2020 ◽  
Vol 52 (1) ◽  
pp. 454-467 ◽  
Author(s):  
P. T. S. Rose ◽  
G. W. Byerley ◽  
E. College ◽  
J. R. Pyle ◽  
D. J. Ralph ◽  
...  
Keyword(s):  
Water Injection ◽  
Fuel Gas ◽  
Oil Reserves ◽  
Lithology Prediction ◽  
The Uk ◽  
4D Seismic ◽  
Bypassed Oil ◽  
Fluid Detection ◽  
Gas Supply ◽  
Regional Aquifer

AbstractThe Forties Field, discovered by BP in 1970, is the largest oilfield on the UK Continental Shelf. It is trapped in a simple four-way dip closure, with a Paleocene turbidite sandstone reservoir. The Forties Field originally contained between 4.2 and 5 billion bbl of oil, with 2.75 billion bbl produced to June 2017. Production has been supported by water injection and the influx of a regional aquifer. The original development contained equally spaced producers with peripheral injectors. As the field matured, production was concentrated in the crestal parts of the field with injectors tending to be moved upflank. With the development of seismic lithology prediction and fluid detection, together with 4D seismic technology, it became possible in the late 1990s to target bypassed oil in unexpected locations throughout the field. In 2003, BP sold the field to Apache who were able to rejuvenate production, adding over 170 MMbbl oil reserves, with an extended drilling campaign targeting bypassed pay identified using seismic technologies. Production at the Forties facility has been further enhanced by the development of four satellite oilfields, Bacchus (Jurassic reservoir), Brimmond, Maule and Tonto (Eocene reservoirs), together with Aviat (Pleistocene reservoir) produced for fuel gas supply.

Aviat: a Lower Pleistocene shallow gas hazard developed as a fuel gas supply for the Forties Field

2016 ◽  
Vol 8 (1) ◽  
pp. 485-505 ◽  
Author(s):  
Phil Rose ◽  
Grant Byerley ◽  
Owen Vaughan ◽  
John Cater ◽  
Brice R. Rea ◽  
...  
Keyword(s):  
North Sea ◽  
Ice Sheet ◽  
Early Pleistocene ◽  
Silty Mudstone ◽  
Shallow Gas ◽  
Fuel Gas ◽  
The North ◽  
Pressure Profiles ◽  
The Uk ◽  
Gas Supply

AbstractThe search for a gas source near to Apache's Forties Field in the North Sea was motivated by the prediction of an ever-increasing fuel gas shortfall as the field oil rate declined. The Central North Sea is well known for a large number of shallow gas hazards in the Pleistocene section that have historically caused blowouts during exploration and development. These gas accumulations typically show up as small bright anomalies on seismic data. In 2009, a large gas anomaly was identified to the east of Forties, and the Aviat Field was discovered in 2010 when exploration well 22/7-5 was drilled.The Aviat Field reservoir is interpreted to be a subaqueous glacial outwash fan, consisting of silt-grade, rock flour material, deposited in front of a grounded ice sheet in some 400 m of water. Aviat sits on an overcompacted silty mudstone that was deformed by this ice sheet – the Crenulate Marker. The distribution of this horizon implies that the Early Pleistocene ice sheet covered at least the northern half of the UK North Sea.Although the Aviat reservoir is thin (2–9 m thick), the well tests, pressure profiles and geophysical response demonstrate that the reservoir is well connected, extensive (over 35 km2) with high deliverability (up to 18 MMscfd achieved). Aviat was sanctioned in 2014 for development as a fuel gas supply for the Forties Field, with first gas achieved in July 2016.

The Birch Field, Block 16/12a, UK North Sea

2003 ◽  
Vol 20 (1) ◽  
pp. 167-181 ◽  
Author(s):  
J. Hook ◽  
A. Abhvani ◽  
J. G. Gluyas ◽  
M. Lawlor
Keyword(s):  
Hanging Wall ◽  
Water Injection ◽  
Oil Production ◽  
Volatile Oil ◽  
Oil Field ◽  
Injection Well ◽  
Current Estimate ◽  
Oil Reserves ◽  
Water Cut ◽  
The Uk

AbstractThe Birch Field is an oil field located in Block 16/12a on the UK Continental Shelf (UKCS) and is part of the well-established 'Brae Trend'. Birch produces an undersaturated volatile oil from the Brae Conglomerate, a locally thick conglomeratic unit within the Late Jurassic Brae Formation. The reservoir was deposited as a small submarine fan in the hanging wall of the main fault bounding the western side of the South Viking Graben. The current estimate for oil in place is about 70MMSTB with expected ultimate oil reserves of 30MMSTB. The field was brought on stream in September 1995 as a phased waterflood subsea development, tied back to Marathon's Brae 'A' platform in neighbouring Block 16/7a. During Phase I the discovery and both appraisal wells were re-completed as two oil producers and one water injection well. Phase II comprised a third oil production well and a second water injection well drilled and completed in 1996-1997. Oil production peaked at c. 28 000 BOPD in the second half of 1996. The field is currently in decline and production in June 1999 was c. 7000 BOPD with a water-cut of c. 40%. Cumulative oil production to end June 1999 was 21 MM STB and remaining oil reserves are estimated as 9MMSTB.

Development of efficiency increase methods for water injection

2020 ◽  
pp. 57-60
Author(s):  
K.I. Mustafaev ◽  
◽  
◽  
Keyword(s):  
Water Injection ◽  
Cost Effective ◽  
Current Interest ◽  
Residual Oil ◽  
Production Well ◽  
Field Development ◽  
Oil Reserves ◽  
Production Wells ◽  
Efficiency Increase

The production of residual oil reserves in the fields being in a long-term exploitation is of current interest. The extraction of residual oil in such fields was cost-effective and simple technological process and is always hot topic for researchers. Oil wells become flooded in the course of time. The appearance of water shows in production wells in the field development and operation is basically negative occurrence and requires severe control. Namely for this reason, the studies were oriented, foremost, to the prevention of water shows in production well and the elimination of its complications as well. The paper discusses the ways of reflux efficiency increase during long-term exploitation and at the final stages of development to prevent the irrigation and water use in production wells.

scholarly journals BACTON SANDSCAPING - BUILDING WITH NATURE TO SAFEGUARD THE UK'S GAS SUPPLY AND HELP COMMUNITIES ADAPT TO COASTAL CHANGE

2020 ◽  
pp. 15
Author(s):  
Jaap Flikweert ◽  
Christine Adnitt
Keyword(s):  
Large Scale ◽  
Beach Nourishment ◽  
Beach Erosion ◽  
Coastal Change ◽  
Erosion Risk ◽  
Natural Processes ◽  
Building With Nature ◽  
The Uk ◽  
Gas Supply

The Bacton Sandscaping scheme is a large-scale beach nourishment, designed to protect the Bacton Gas Terminal from cliff and beach erosion while also reducing flood and erosion risk to the communities of Bacton and Walcott, buying the time they need for adaptation to coastal change. The scheme was inspired by the even larger Dutch Zandmotor project, translating the concept to the different geography and governance setting of the UK - it can be seen as the Zandmotor's 'little nephew'. The term 'Sandscaping' was introduced to illustrate the large-scale and ambitious nature of the concept: work at a large scale, designing to work with natural processes and to achieve multiple objectives.Recorded Presentation from the vICCE (YouTube Link): https://youtu.be/FA3DjdCgKrk

scholarly journals Comparative Study on Fuel Gas Supply Systems for LNG Bunkering Using Carbon Dioxide and Glycol Water

2019 ◽  
Vol 7 (6) ◽  
pp. 184 ◽  
Author(s):  
Jungho Choi ◽  
Eun-Young Park
Keyword(s):  
Heat Exchanger ◽  
Water System ◽  
Specific Power ◽  
Fuel Gas ◽  
Aspen Hysys ◽  
Lng Fuel ◽  
Main Component ◽  
Supply Systems ◽  
Significant Attention ◽  
Gas Supply

Liquified natural gas (LNG) fuel has received significant attention as an affordable and highly efficient fuel option due to strengthened regulations on the sulfur content of bunker oil put in place by the International Maritime Organization. The main component of the LNG fuel gas supply system (FGSS) is the heat exchanger that provides adequate gas temperatures and pressures required by the engine, which also has a large machinery volume compared with other equipment. Due to the volume limitation, most FGSS have been applied to new shipbuilding only. To reduce the volume of the FGSS, CO2 was considered to serve as the replacement heat medium for conventionally used glycol water during LNG gasification. The specific power consumption (SPC) in the CO2 and glycol water system was optimized using the Aspen HYSYS thermodynamic modeler toward adjusting the temperature and pressure, and the resulting sizes were compared. This study demonstrated that the CO2 heat medium resulted in a 14% improvement in efficiency and a 7% reduction in heat exchanger size concluding that it was the most advantageous heat medium for the LNG regasification.

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