The Golden Eagle, Peregrine and Solitaire fields, Blocks 14/26a and 20/01, UK North Sea

2020 ◽  
Vol 52 (1) ◽  
pp. 740-754 ◽  
Author(s):  
S. J. Pinnock ◽  
D. M. Dutton
Keyword(s):  
Upper Jurassic ◽  
Production Performance ◽  
Ocean Bottom ◽  
Golden Eagle ◽  
Sweep Efficiency ◽  
Initial Development ◽  
Start Up ◽  
Moray Firth ◽  
Interference Tests ◽  
Phase Production

AbstractThe Golden Eagle Field is located 18 km north of the Buzzard Field in the Moray Firth, and consists of oil accumulations in the Lower Cretaceous Punt and Upper Jurassic Burns Sandstone members. The development area comprises three fields, Golden Eagle, Peregrine and Solitaire, but up to 90% of the oil-in-place and ultimate recovery are in Golden Eagle. The two satellite fields are primarily structural closures, while the Golden Eagle Field reservoirs have a major element of stratigraphic pinchout. Production commenced in October 2014 and approximately 140 MMbbl of recoverable oil is anticipated over its field life from the 19 development wells (14 producers and 5 injectors) that form the initial development phase. Production performance to date has exceeded expectations, aided through the use of completions that provide zonal control of the reservoir units which has successfully supported reservoir management and improved sweep efficiency.A number of significant lessons have been learned during the early stages of the field life from the integration of dynamic data (real-time downhole fibre-optic reservoir monitoring instruments, inter- and intra-well tracers, and well interference tests) and seismic data improvements (post-start-up acquisition of high-density ocean-bottom node seismic and depth-conversion improvements).

4D Ocean Bottom Node Decimation Study over the North Sea Golden Eagle Field

2020 ◽  
Author(s):  
I. Gregory ◽  
Z. Dobo ◽  
F. Ebrahim ◽  
J. Sinden ◽  
P. McDonnell ◽  
...  
Keyword(s):  
North Sea ◽  
Ocean Bottom ◽  
Golden Eagle ◽  
The North ◽  
The North Sea

The Ivanhoe and Rob Roy Fields, Blocks 15/21a-b, UK North Sea

1991 ◽  
Vol 14 (1) ◽  
pp. 331-338 ◽  
Author(s):  
R. H. Parker
Keyword(s):  
North Sea ◽  
Upper Jurassic ◽  
Rock Properties ◽  
Production Facility ◽  
Injection Wells ◽  
Recoverable Reserves ◽  
Fault Block ◽  
Moray Firth ◽  
Sandstone Formation ◽  
Northeast Coast

AbstractThe Ivanhoe and Rob Roy Fields are located in the Outer Moray Firth Basin, seventy nautical miles off the northeast coast of Scotland. The Ivanhoe Field was discovered in 1975, and the Rob Roy Field in 1984. The reserves in both fields occur in tilted fault block traps of Upper Jurassic, Piper Sandstone Formation. Estimated total recoverable reserves amount to 100 MMBBL and 62 BCF. The fields are separated by a water corridor approximately 1 km wide. Both fields contain two reservoir sandstone units, an upper and lower, locally termed the Supra Piper Sandstone and Main Piper Sandstone respectively. The reservoirs in both fields exhibit excellent rock' properties with porosities up to 28% and permeabilities of several Darcies.Each field is developed via a subsea manifold surrounded by a cluster of production and injection wells, of which two were pre-drilled on Ivanhoe and six pre-drilled on Rob Roy. This allowed rapid achievement of the 60 000 BOPD plateau oil production rate soon after commissioning of facilities in July 1989. The two subsea manifolds are tied into a single subsea production manifold which connects with a Floating Production Facility. Crude oil is exported to the Claymore A Platform and gas to the Tartan A Platform.

Are you an innovator or adaptor? the impact of cognitive propensity on venture expectations and outcomes

2008 ◽  
Vol 11 (2) ◽  
pp. 29-45 ◽  
Author(s):  
Kevin LaMont Johnson ◽  
Wade M. Danis ◽  
Marc J. Dollinger
Keyword(s):  
Problem Solving ◽  
Cognitive Style ◽  
Nascent Entrepreneurs ◽  
Initial Development ◽  
Start Up ◽  
The Impact

In this study we confirm the often assumed but largely untested belief that entrepreneurs think and behave differently than others. We examine a group of more than 700 nascent entrepreneurs and 400 nonentrepreneurs. We determine the entrepreneurs’ cognitive style propensity for problem solving (Innovator versus Adaptor); we compare their expectations; and, we examine the outcomes (performance and start-up) of their ventures. We find that nascent entrepreneurs are more likely to be overly optimistic Innovators, most people are Adaptors, and oneʼs cognitive style can indeed play a role in the initial development and outcome for the venture, but not always as expected.

scholarly journals Design practices for strategic innovation in start-ups

2019 ◽  
Vol 2 (1) ◽  
Author(s):  
Daphna GLAUBERT ◽  
Zarina CHARLESWORTH ◽  
Nathalie NYFFELER ◽  
Luc BERGERON ◽  
Luc BERGERON
Keyword(s):  
Early Stage ◽  
Self Report ◽  
Initial Development ◽  
Design Practices ◽  
Strategic Innovation ◽  
Stage Of Development ◽  
Start Up ◽  
Product Service ◽  
Working Together ◽  
Start Ups

This paper looks at the use of design practices in start-up firms for the creation of strategic advantage through product/service innovation. Start-ups face non-negligible challenges during the early-stage of development. The research questions examined to what extent design practices can provide the leverage needed to face these challenges. A 4-day Innovation by Design Challenge workshop provided the field for the research carried out. Participants were start-up firms each working together with two designers to form six teams. Methods used included: observation for the mapping of team activities; a short self-report questionnaire and; pre- and post-workshop semi-directed interviews with the start-ups. The findings support the idea that design practice integration into the initial development of a start-up can indeed provide a lever for success and provide the start-up with the strategic vision needed to go through the early-stage and bring their products/services to market successfully.

The Buzzard Field, Blocks 19/5a, 19/10a, 20/1 and 20/6a, UK North Sea

2020 ◽  
Vol 52 (1) ◽  
pp. 691-704 ◽  
Author(s):  
E. E. Taylor ◽  
N. J. Webb ◽  
C. J. Stevenson ◽  
J. R. Henderson ◽  
A. Kovac ◽  
...  
Keyword(s):  
North Sea ◽  
Upper Jurassic ◽  
Depositional Model ◽  
Performance Expectations ◽  
North West ◽  
Field Development ◽  
The North ◽  
Moray Firth ◽  
The North Sea ◽  
Clay Formation

AbstractThe Buzzard Field remains the largest UK Continental Shelf oil discovery in the last 25 years. The field is located in the Outer Moray Firth of the North Sea and comprises stacked Upper Jurassic turbidite reservoirs of Late Kimmeridgian–Mid Volgian age, encased within Kimmeridge Clay Formation mudstones. The stratigraphic trap is produced by pinchout of the reservoir layers to the north, west and south. Production commenced in January 2007 and the field has subsequently produced 52% over the estimated reserves at commencement of development, surpassing initial performance expectations. Phase I drilling was completed in 2014 with 38 wells drilled from 36 platform slots. Platform drilling recommenced in 2018, followed in 2019 by Phase II drilling from a new northern manifold location.The evolution of the depositional model has been a key aspect of field development. Integration of production surveillance and dynamic data identified shortcomings in the appraisal depositional model. A sedimentological study based on core reinterpretation created an updated depositional model, which was then integrated with seismic and production data. The new depositional model is better able to explain non-uniform water sweep in the field resulting from a more complex sandbody architecture of stacked channels prograding over underlying lobes.

The Shearwater Field, Blocks 22/30b and 22/30e, UK North Sea

2020 ◽  
Vol 52 (1) ◽  
pp. 574-588 ◽  
Author(s):  
B. J. Taylor ◽  
D. W. Jones
Keyword(s):  
Near Field ◽  
Upper Jurassic ◽  
Lessons Learned ◽  
Main Field ◽  
Initial Field ◽  
Initial Development ◽  
Field Development ◽  
Production Platform ◽  
Production Wells ◽  
Exploration And Production

AbstractThe Shearwater Field is a high-pressure–high-temperature (HPHT) gas condensate field located 180 km east of Aberdeen in UKCS Blocks 22/30b and 22/30e within the East Central Graben. Shell UK Limited operates the field on behalf of co-venturers Esso Exploration and Production UK Limited and Arco British Limited, via a fixed steel jacket production platform and bridge-linked wellhead jacket in a water depth of 295 ft.Sandstones of the Upper Jurassic Fulmar Formation constitute the primary reservoir upon which the initial field development was sanctioned; however, additional production has been achieved from intra-Heather Formation sandstones, as well as from the Middle Jurassic Pentland Formation. Following first gas in 2000, a series of well failures occurred such that by 2008 production from the main field Fulmar reservoir had ceased. This resulted in a shut-in period for the main field from 2010 before a platform well slot recovery and redevelopment drilling campaign reinstated production from the Fulmar reservoir in 2015. In addition to replacement wells, the redevelopment drilling also included the design and execution of additional wells targeting undeveloped reservoirs and near-field exploration targets, based on the lessons learned during the initial development campaign, resulting in concurrent production from all discovered reservoirs via six active production wells by 2018.

A New Diagnostic Analysis Method for Waterflood Performance

2009 ◽  
Vol 12 (02) ◽  
pp. 341-351 ◽  
Author(s):  
Zhengming Yang
Keyword(s):  
Relative Permeability ◽  
Oil Recovery ◽  
Production Performance ◽  
Hydraulic Fractures ◽  
Diagnostic Analysis ◽  
Fractional Flow ◽  
Permeability Ratio ◽  
Sweep Efficiency ◽  
Widespread Application ◽  
Time Plot

Summary Despite the widespread application of reservoir simulation to study waterflood reservoirs, petroleum engineers still need simple predictive tools to forecast production decline, estimate ultimate oil recovery, and diagnose the production performance from the historical field data. On the basis of the Buckley-Leverett equation and the assumption of a semilog relationship between the oil-to-water relative permeability ratio and water saturation, a consistent analytical solution can be derived as:qoD (1 - qoD) = (EV /B)(1 / tD) where qoD is the oil fractional flow, tD is the fraction of cumulative liquid production to related formation volume, B is the relative permeability ratio parameter, and EV is the volumetric sweep efficiency. Two equivalent linear plots can be developed: a log-log plot and a reciprocal time plot. The log-log plot has a slope of -1 and intercept of EV /B. The reciprocal time plot has a slope of EV /B and an intercept value of 0. Both plots can be applied for the diagnostic analysis of waterflood reservoirs. Model and field case studies show the benefits of this technique as a production-decline analysis tool in forecasting the waterflood production decline and the ultimate oil recovery. This method can also be applied as a diagnostic tool to evaluate various aspects of waterflood performance. Examples include assessing waterflood maturity, calculating volumetric sweep efficiency, distinguishing the normal waterflood breakthrough from the premature water breakthrough through hydraulic fractures, and examining the consequences of operational changes. The appropriate use of this analytical method will help to optimize the field waterflood operation.

The Kingfisher Field, Block 16/8a, UK North Sea

2003 ◽  
Vol 20 (1) ◽  
pp. 305-314 ◽  
Author(s):  
Samantha Spence ◽  
Helge Kreutz
Keyword(s):  
Hydrocarbon Composition ◽  
Upper Jurassic ◽  
Gas Condensate ◽  
Production Performance ◽  
Horizontal Drilling ◽  
Field Development ◽  
Reservoir Architecture ◽  
Production Wells ◽  
Medium Quality ◽  
A Minor

AbstractThe Kingfisher Field is located in the South Viking Graben, Block 16/8a, with a minor extension into Block 16/8c. Block 16/8 was initially awarded in June 1970 to Shell and Esso, with the Kingfisher discovery well 16/8-1 spudded in 1972. The well tested high H2S oil at marginal rates from Upper Jurassic Brae Formation sandstones. Subsequent appraisal well 16/8a-4 (1984) tested gas/condensate from better quality Brae Formation sandstone reservoirs. This well also discovered the deeper Middle Jurassic Heather Formation sandstone gas/condensate accumulation at near-HPHT conditions. The Brae and Heather Formation sandstones contain stacked hydrocarbon accumulations in separate combinations of stratigraphic and structural traps. Production by natural aquifer drive commenced from a sub-sea satellite to Marathon's Brae B platform in 1997, initially from the Brae reservoirs. To date, three production wells have been completed and a fourth well is planned to be on stream in 2000. The Brae Formation sandstones at Kingfisher are interpreted as distal deposits of the Brae/Miller fan-apron system and range in quality from excellent to very poor across the field. The Heather Formation reservoir consists of medium quality sands deposited within a submarine incised valley. The most recent volumetric estimate (1998) for the total field predicts an ultimate recovery of 41.2 MMBBL of pipeline liquids and 280 BCF of dry export gas. Regional reservoir architecture and connectivity as well as hydrocarbon composition are key to understanding the production performance of the critical gas/condensate below dewpoint. Advances in sub-sea and horizontal drilling technology have enabled field development.

Stratigraphic development of an Upper Jurassic deep marine syn-rift succession, Inner Moray Firth Basin, Scotland

2012 ◽  
Vol 25 (3) ◽  
pp. 285-309 ◽  
Author(s):  
Adam D. McArthur ◽  
Adrian J. Hartley ◽  
David W. Jolley
Keyword(s):  
Upper Jurassic ◽  
Moray Firth
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