J. Gluyas, M. Słowakiewicz, M. Tucker, P. Gutteridge
{"title":"The Morag Field, Block 16/29a, UK North Sea","authors":"J. Gluyas, M. Słowakiewicz, M. Tucker, P. Gutteridge","doi":"10.1144/M52-2018-90","DOIUrl":"https://doi.org/10.1144/M52-2018-90","url":null,"abstract":"Abstract The Morag Field is a small oilfield underlying the Maureen Field in UK Block 16/29a. Black oil is trapped within Upper Permian, Morag Member, vuggy and fractured dolomite rafts between 9300 and 10 600 ft true vertical depth subsea. The dolomite reservoir occurs at the top of a Zechstein salt dome. Morag was discovered in 1979 by well 16/29a-A1, the first platform well drilled for the overlying Maureen Field with its Paleocene sandstone reservoir. Morag was produced via a single well (16/29a-A1) between 1991 and 1994. Three more platform wells were drilled into the Permian interval prior to Maureen Field start up but only one penetrated oil-bearing dolomite (16/29a-A2). An additional well (16/29a–A23Z) was drilled into the Morag Field in 1993. The well encountered Morag Member at virgin pressure and tested oil at high flow rate but then the well failed due to mechanical problems. Oil in place was calculated to be about 24 MMbbl in four independent fault blocks. Ultimately 16/29a-A1 delivered 2.6 MMbbl from a fault block calculated to have held 6.7 MMbbl stock tank oil initially in place.","PeriodicalId":84271,"journal":{"name":"Biological memoirs","volume":"19 1","pages":"897 - 905"},"PeriodicalIF":0.0,"publicationDate":"2020-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85051022","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
{"title":"The Cavendish Field, Block 43/19, UK North Sea","authors":"N. Wasielka, J. Gluyas, H. Breese, R. Symonds","doi":"10.1144/M52-2019-10","DOIUrl":"https://doi.org/10.1144/M52-2019-10","url":null,"abstract":"Abstract The Cavendish Field is located in UK Continental Shelf Block 43/19a on the northern margin of the Outer Silverpit Basin of the Southern North Sea, 87 miles (140 km) NE of the Lincolnshire coast in a water depth of 62 ft (18.9 m). The Cavendish Field is a gas field in the upper Carboniferous Namurian C (Millstone Grit Formation) and Westphalian A (Caister Coal Formation) strata. It was discovered in 1989 by Britoil-operated well 43/19-1. Production started in 2007 and ceased in 2018. Gas initially in place was 184 bcf and at end of field life 98 bcf had been produced. The field was developed by three wells drilled through the normally unmanned platform into fluvio-deltaic sandstone intervals that had sufficiently good reservoir quality to be effective reservoirs. The majority of the formation within closure comprises mudstones, siltstones and low permeability, non-reservoir-quality feldspathic sandstones. The quality of the reservoir is variable and is controlled by grain size, feldspar content and diagenesis. The field is a structural trap, sealed by a combination of intra-Carboniferous mudstones and a thick sequence of Permian mudstones and evaporites.","PeriodicalId":84271,"journal":{"name":"Biological memoirs","volume":"96 1","pages":"131 - 141"},"PeriodicalIF":0.0,"publicationDate":"2020-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87689278","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
{"title":"Atlantic Margin, East Shetland Basin and North Viking Graben","authors":"","doi":"10.1144/m52.2","DOIUrl":"https://doi.org/10.1144/m52.2","url":null,"abstract":"","PeriodicalId":84271,"journal":{"name":"Biological memoirs","volume":"16 1","pages":"NP - NP"},"PeriodicalIF":0.0,"publicationDate":"2020-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84501566","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
{"title":"The Cygnus Field, Blocks 44/11a and 44/12a, UK North Sea","authors":"I. Dredge, G. Marsden","doi":"10.1144/M52-2018-69","DOIUrl":"https://doi.org/10.1144/M52-2018-69","url":null,"abstract":"Abstract The Cygnus Field is located in Blocks 44/11a and 44/12a of the UK Southern North Sea. The field was first discovered in 1988 as a tight lower Leman Sandstone Formation gas discovery by well 44/12- 1. After the licences had sat idle for several years, GDF Britain (now Neptune E&P UK Ltd) appraised the field from 2006 to 2010. During the appraisal phase, the lower Leman Sandstone was found to be of better quality than first discovered and the gas-bearing lower Ketch Member reservoir was also encountered. The field development was sanctioned in 2012. The field has been developed from two wellhead platforms targeting Leman Sandstone and Ketch Member reservoirs. Five main fault blocks have been developed, with two wells in each fault block planned in the field development plan. The wells are long horizontal wells completed with stand-alone sand screens. At the time of writing, the production plateau is 320 MMscfgd (266 MMscfgd when third-party constraints apply), producing from nine wells with the final production well to be drilled.","PeriodicalId":84271,"journal":{"name":"Biological memoirs","volume":"7 1","pages":"151 - 162"},"PeriodicalIF":0.0,"publicationDate":"2020-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84420567","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
J. Clark, D. Mazzuchelli, M. Rowlands, N. Jebara, C. Parry
{"title":"The Edradour Field, Block 206/4a, UK Atlantic Margin","authors":"J. Clark, D. Mazzuchelli, M. Rowlands, N. Jebara, C. Parry","doi":"10.1144/M52-2018-23","DOIUrl":"https://doi.org/10.1144/M52-2018-23","url":null,"abstract":"Abstract The Edradour Field, located in Licence P1453 on Block 206/4a of the Faroe–Shetland Basin, was put on production in August 2017. It lies c. 50 km NW of the Shetland Islands in a water depth of c. 300 m, and consists of one subsea well that produces gas condensate from the Albian Black Sail Member of the Commodore Formation. It is part of a joint development scheme along with the Glenlivet Field that sees the commingled multiphase production transported to the Shetland Gas Plant via tieback to the pre-existing Laggan–Tormore flowlines. The Edradour single well development has reserves of 21 MMboe from a gas initially-in-place of 142 bcf. It is operated by Total E&P UK Ltd under the P1453 licence with Ineos E&P (UK) Ltd and SSE E&P UK Ltd as partners.","PeriodicalId":84271,"journal":{"name":"Biological memoirs","volume":"58 1","pages":"952 - 957"},"PeriodicalIF":0.0,"publicationDate":"2020-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81560523","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
P. Rose, G. Byerley, E. College, J. Pyle, D. Ralph, P. Rowbotham, L. A. van Oorschot, J. Towart, O. Vaughan, M. Vermaas
{"title":"The Forties Field, Blocks 21/10 and 22/6a, UK North Sea","authors":"P. Rose, G. Byerley, E. College, J. Pyle, D. Ralph, P. Rowbotham, L. A. van Oorschot, J. Towart, O. Vaughan, M. Vermaas","doi":"10.1144/M52-2017-41","DOIUrl":"https://doi.org/10.1144/M52-2017-41","url":null,"abstract":"Abstract The 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.","PeriodicalId":84271,"journal":{"name":"Biological memoirs","volume":"2014 1","pages":"454 - 467"},"PeriodicalIF":0.0,"publicationDate":"2020-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86786810","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
P. Rouillard, G. Bagley, David Moseley, K. Myers, Alyson Harding
{"title":"UKCS exploration: 50 years and counting","authors":"P. Rouillard, G. Bagley, David Moseley, K. Myers, Alyson Harding","doi":"10.1144/M52-2018-66","DOIUrl":"https://doi.org/10.1144/M52-2018-66","url":null,"abstract":"Abstract Exploration drilling activity, discovery history and creaming curves in the offshore UK are analysed for each UK Continental Shelf (UKCS) basin and each play in the North Sea from the earliest wells drilled in 1965 until the end of 2017. Around 52 Bboe of commercially recoverable oil and gas has been discovered, with around half of this volume found in the first 10 years of exploration. UKCS exploration plays are generally at a mature or super-mature stage and the exploration challenges reflect this. Although technical success rates have steadily increased since the 1990s, pool sizes are becoming smaller. In the last 10 years the average commercial discovery size has been 27 MMboe recoverable, and since 2010 only 10% of discoveries have been bigger than 43 MMboe recoverable. The UK Oil and Gas Authority's 6 Bboe mid-case yet-to-find estimate, as published in 2018, would take 40 years to unlock at the current rate of discovery. Future exploration in the mature UKCS is intertwined with prolonging the life of production infrastructure and is increasingly dependent on the development of new low-cost development concepts. Increased focus on the search for subtle traps, and more reliable pre-drill risk and volume estimation through improved benchmarking and calibration will be key to future exploration success.","PeriodicalId":84271,"journal":{"name":"Biological memoirs","volume":"11 1","pages":"32 - 42"},"PeriodicalIF":0.0,"publicationDate":"2020-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83425225","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
{"title":"The Renee Field, Block 15/27a, UK North Sea","authors":"G. Tegerdine","doi":"10.1144/M52-2017-27","DOIUrl":"https://doi.org/10.1144/M52-2017-27","url":null,"abstract":"Abstract The Renee Field lies in Block 15/27 toward the eastern end of the Renee Ridge, a major intra-basinal high in the Outer Moray Firth separating the Witch Ground Graben and South Halibut Graben. The block was awarded to a Phillips Petroleum-led consortium in the fourth Round of UKCS Licensing in March 1972. The 15/27-1 discovery well was drilled in 1976, testing oil at rates of 8025 bopd from stacked Piper/Upper Scott sandstone reservoirs. The field was appraised in mid-1997 and an Annex B submitted to the Department of Trade and Industry in late 1997 for a joint Renee and Rubie Field development. Oil export was via a 21 km pipeline to the Ivanhoe/Rob Roy fields, north of Renee. The development comprised a three-well drilling programme, completed in August 1999. First production was achieved in February 1999 at rates of up to 20 000 bopd, the plateau period continuing until year end. Production continued to decline until the field was permanently shut-in during September 2006. Ultimate recovery was 8.9 MMbbl and recovery factor 49%, based on a final mapped stock tank oil-in-place of 18.2 MMbbl. Decommissioning of the Renee Field commenced in 2015 with the removal of the subsea infrastructure.","PeriodicalId":84271,"journal":{"name":"Biological memoirs","volume":"15 1","pages":"779 - 789"},"PeriodicalIF":0.0,"publicationDate":"2020-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78027250","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
{"title":"Appendix A: Sources of additional data on each field","authors":"","doi":"10.1144/M52-018-55","DOIUrl":"https://doi.org/10.1144/M52-018-55","url":null,"abstract":"Fields in production are current to July 2020 OGA listing of consented fields. References listed include all relevant Geological Society (GSL) publications including the Petroleum Geology Conference series 1–8 (only 4–8 published by GSL), and PESGB DEVEX presentations up to and including DEVEX 2019, with content from multiple additional sources. Papers published by the Society of Petroleum Engineers are not routinely listed below but can be readily searched online via www.onepetro.org.","PeriodicalId":84271,"journal":{"name":"Biological memoirs","volume":"25 1","pages":"1015 - 1062"},"PeriodicalIF":0.0,"publicationDate":"2020-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89505427","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
{"title":"The Breagh Field, Blocks 42/12a, 42/13a and 42/8a, UK North Sea","authors":"C. M. Nwachukwu, Z. Barnett, J. Gluyas","doi":"10.1144/M52-2019-15","DOIUrl":"https://doi.org/10.1144/M52-2019-15","url":null,"abstract":"Abstract The Breagh Field is in UK Blocks 42/12a, 42/13a and 42/8a. It is a gas field with multiple reservoir intervals within sandstones of the Early Carboniferous Yoredale Formation (equivalent to the Middle Limestone Formation within the Yoredale Group onshore). It was the first and is presently the only field developed within these sandstones, offshore UK. Breagh was discovered in 1997 by well 42/13-2 and proved by development well 42/13a-A1. Its crest is at 7110 ft TVDSS (true vertical depth subsea), marked by the unconformity between the base Zechstein and the subcropping Yoredale Formation. It has a free water level at 7690 ft TVDSS, a maximum column height of 510 ft and a field extent of 94 km2. Breagh was developed using ten wells from a 12 slot normally unattended platform; five of the wells have been stimulated by hydraulic fractures with proppant injection. The unprocessed gas flows through a 110 km 20-inch diameter pipeline to the Teesside Gas Processing Plant. Production started in 2013, reached a peak rate of 150 MMscfgd in 2014 and, by the end of 2018, had produced 140 bcf. The field is operated by INEOS Oil and Gas UK Ltd (70%) with partner ONE-Dyas B.V. (30%).","PeriodicalId":84271,"journal":{"name":"Biological memoirs","volume":"62 1","pages":"109 - 118"},"PeriodicalIF":0.0,"publicationDate":"2020-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74583509","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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