Field map

2003 ◽  
Vol 20 (1) ◽  
pp. 394-394
Keyword(s):  
North Sea ◽  
Oil And Gas ◽  
Median Line ◽  
The South ◽  
Moray Firth ◽  
The Uk ◽  
Central North Sea ◽  
International Border

AbstractMap depicting the position and names of the main oil and gas producing fields located in the South Viking Graben, Inner and Outer Moray Firth Basins and Central Graben areas of the Central North Sea. The international border (median line) between the UK and Norway is highlighted as are the producing fields in the Norwegian sector. The boxed areas show the extent of licensed acreage in the region.

Field map

2003 ◽  
Vol 20 (1) ◽  
pp. 62.2-62
Keyword(s):  
North Sea ◽  
Oil And Gas ◽  
Median Line ◽  
The South ◽  
Moray Firth ◽  
The Uk ◽  
Central North Sea ◽  
International Border

AbstractMap depicting the position and names of the main oil and gas producing fields located in the South Viking Graben, Inner and Outer Moray Firth Basins and Central Graben areas of the Central North Sea. The international border (median line) between the UK and Norway is highlighted as are the producing fields in the Norwegian sector. The boxed areas show the extent of licensed acreage in the region.

Field map

2003 ◽  
Vol 20 (1) ◽  
pp. 132-132
Keyword(s):  
North Sea ◽  
Oil And Gas ◽  
Median Line ◽  
Moray Firth ◽  
The Uk ◽  
Central North Sea ◽  
International Border

AbstractMap depicting the position and names of the main oil and gas producing fields located in the Viking Graben and eastern parts of the Outer Moray Firth rift arms, Northern and Central North Sea. The international border (median line) between the UK and Norway is highlighted as are the producing fields in the Norwegian sector. The boxed areas show the extent of licensed acreage in the region.

Exploration well failures from the UK North Sea

2016 ◽  
Vol 8 (1) ◽  
pp. 267-272 ◽  
Author(s):  
Christian J. H. Mathieu
Keyword(s):  
Peer Review ◽  
North Sea ◽  
Primary Reason ◽  
Success Rates ◽  
Moray Firth ◽  
The Uk ◽  
Central North Sea ◽  
Exploration Well ◽  
Play Context

AbstractThe UK Oil & Gas Authority carried out post-well failure analyses of exploration and appraisal wells in the Moray Firth and the UK Central North Sea to fully understand the basis for drilling the prospects and the reasons why the prospects failed.The data consisted of Tertiary, Mesozoic and Palaeozoic targets/segments associated with 97 wells drilled from 2003 to 2013. Seal was the primary reason for failure followed by trap, reservoir and charge. Root causes for failure were a lack of lateral seal, the absence of the target reservoir and the lack of a trap. The main pre-drill risk was not accurately predicted in over one-third of the cases and a third of the segments were targeted on the basis of perceived Direct Hydrocarbon Indicators.This study identified a number of interpretation gaps and pitfalls that ultimately contributed to the well failures. These included poor integration, improper application of geophysics, lack of regional play context, and absent or ineffective peer review. Addressing these gaps in a comprehensive and systematic way is fundamental to improving exploration success rates.

Field map

2003 ◽  
Vol 20 (1) ◽  
pp. 662-662
Keyword(s):  
The Netherlands ◽  
North Sea ◽  
Median Line ◽  
Southern North Sea ◽  
The Uk ◽  
International Border

AbstractMap depicting the position and names of the main gas producing fields located in the Southern North Sea. The international border (median line) between the UK and The netherlands is highlighted as are the producing fields Iincluding one small oil producer) in the neighbouring Dutch sector. The boxed areas show the extent of licensed acreage in the region.

Field map

2003 ◽  
Vol 20 (1) ◽  
pp. 120-120
Keyword(s):  
Oil And Gas ◽  
Median Line ◽  
Oil And Gas Fields ◽  
The Uk ◽  
Gas Fields ◽  
International Border

AbstractMap depicting the position and names of the main oil and gas fields and important undeveloped discoveries located in the Faroe-Shetland Basin, West of Shetland. The international border (median line) between the UK and the Faores is highlighted. The boxed areas show the extent of the licensed acreage in the region.

The Enoch Field, Block 16/13a, UK North Sea

2020 ◽  
Vol 52 (1) ◽  
pp. 828-836 ◽  
Author(s):  
K. Robertson ◽  
R. Heath ◽  
A. McKenzie
Keyword(s):  
North Sea ◽  
Oil Production ◽  
Early Eocene ◽  
Median Line ◽  
The South ◽  
Production Rates ◽  
Stock Tank ◽  
Water Cut ◽  
The Uk

AbstractThe Enoch Field is located in the South Viking Graben and straddles the UK/Norway median line with 80% of the field in the UK and 20% in Norway. Enoch produces undersaturated oil from the Early Eocene-age Flugga Sandstone Member of the Sele Formation. Hydrocarbons have been trapped by a combination of compaction-related dip closure and sand pinchout. The current stock tank oil initially in place estimate is c. 42 MMbbl with expected ultimate recovery of 11.5 MMbbl. The field was brought onstream in May 2007 via a single horizontal subsea gas-lifted well tied back to the Brae Alpha platform. Initial oil production rates were c. 11 800 bopd. The field is currently in decline and in December 2018 production was c. 1800 bopd with 80% water-cut. Cumulative oil production to the end of 2018 was 10.581 MMbbl.

Triassic mudstones of the Central North Sea: cross-border characterization, correlation and their palaeoclimatic significance

2020 ◽  
pp. SP494-2019-61
Author(s):  
Stuart G. Archer ◽  
Tom McKie ◽  
Steven D. Andrews ◽  
Anne D. Wilkins ◽  
Matt Hutchison ◽  
...  
Keyword(s):  
North Sea ◽  
Large Scale ◽  
Regional Scale ◽  
Climatic Conditions ◽  
Fluvial Systems ◽  
Correlation Lengths ◽  
Cross Border ◽  
The Uk ◽  
Stratigraphic Nomenclature ◽  
Central North Sea

AbstractThe Triassic of the Central North Sea is a continental succession that contains prolific hydrocarbon-bearing fluvial sandstone reservoirs stratigraphically partitioned by mudstones. Within the Skagerrak Formation of the UK sector, hydrocarbon accumulations in the Judy, Joanne and Josephine Sandstone members are top sealed by the Julius, Jonathan and Joshua Mudstone members, respectively. However, UK and Norwegian stratigraphic correlations have been problematical for decades, largely due to biostratigraphic challenges but also due to the non-uniqueness of the lithotypes and because the cross-border stratigraphic nomenclature differs and has yet to be rationalized. This study focuses on mudstones rather than sandstones to unify cross-border correlation efforts at a regional scale. The mudstone members have been characterized by integrating sedimentological, petrophysical and geophysical data. The facies are indicative of playa lakes that frequently desiccated and preserved minor anhydrite. These conditions alternated with periods of marshy, palustrine conditions favourable for the formation of dolostones. Regional correlations have detected lateral facies changes in the mudstones which are important for their seismically mappable extents, resulting palaeogeographies and, ultimately, their competency as intraformational top seals. Significant diachroneity is associated with the lithological transitions at sandstone–mudstone member boundaries and although lithostratigraphic surfaces can be used as timelines over short distances (e.g. within a field), they should not be assumed to represent timelines over longer correlation lengths. Palaeoclimatic trends are interpreted and compared to those of adjacent regions to test the extent and impact of climate change as a predictive allogenic forcing factor on sedimentation. Mudstone member deposition occurred as a result of the retreat of large-scale terminal fluvial systems during a return to more arid ‘background’ climatic conditions. The cause of the member-scale climatic cyclicity observed within the Skagerrak Formation may be related to volcanic activity in large igneous provinces which triggered the episodic progradation of fluvial systems.

The MacCulloch Field, Block 15/24b, UK North Sea

2003 ◽  
Vol 20 (1) ◽  
pp. 453-466 ◽  
Author(s):  
C. Gunn ◽  
J. A. MacLeod ◽  
P. Salvador ◽  
J. Tomkinson
Keyword(s):  
North Sea ◽  
Water Contact ◽  
Northern Flank ◽  
Recoverable Reserves ◽  
Average Porosity ◽  
Oil Water ◽  
The Witch ◽  
The Uk ◽  
Clay Formation ◽  
Central North Sea

AbstractThe MacCulloch Field lies within Block 15/24b in the UK Central North Sea and is located on the northern flank of the Witch Ground Graben. It was discovered by Conoco well 15/24b-3 in 1990.MacCulloch Field is a four-way dip closure at Top Paleocene over a deeper Mesozoic structure. The reservoir consists of Upper Balmoral Sandstones containing 32-37° API oils derived from Kimmeridge Clay Formation shales and sealed by shales belonging to the Sele Formation. The field contains recoverable reserves of 60-90 MMBOE.Reservoir quality is generally very good, with an average porosity of 28% and core permeabilities (Kh) between 200 mD and 2D. AVO anomalies and a seismic flat spot are associated with oil filled reservoir and the oil-water contact in certain areas of the field.

The Machar Field, Block 23/26a, UK North Sea

2020 ◽  
Vol 52 (1) ◽  
pp. 523-536 ◽  
Author(s):  
Zoë Sayer ◽  
Jonathan Edet ◽  
Rob Gooder ◽  
Alexandra Love
Keyword(s):  
North Sea ◽  
Debris Flows ◽  
Water Injection ◽  
Salt Diapir ◽  
Reservoir Quality ◽  
Complex Interplay ◽  
Light Oil ◽  
High Matrix ◽  
The Uk ◽  
Central North Sea

AbstractMachar is one of several diapir fields located in the Eastern Trough of the UK Central North Sea. It contains light oil in fractured Cretaceous–Danian chalk and Paleocene sandstones draped over and around a tall, steeply-dipping salt diapir that had expressed seafloor relief during chalk deposition. The reservoir geology represents a complex interplay of sedimentology and evolving structure, with slope-related redeposition of both the chalk and sandstone reservoirs affecting distribution and reservoir quality. The best reservoir quality occurs in resedimented chalk (debris flows) and high-density turbidite sandstones. Mapping and characterizing the different facies present has been key to reservoir understanding.The field has been developed by water injection, with conventional sweep in the sandstones and imbibition drive in the chalk. Although the chalk has high matrix microporosity, permeability is typically less than 2 mD, and fractures are essential for achieving high flow rates; test permeabilities can be up to 1500 mD. The next phase of development is blowdown, where water injection is stopped and the field allowed to depressurize. This commenced in February 2018.

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