Maximizing production and reserves from offshore heavy oil fields using seismic and drilling technology: Alba and Captain Fields, UKNS

Hampson, John; Walden, Skip; Bell, Charles L.

doi:10.1144/0070337

PGC

2010

DOI: 10.1144/0070337

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Maximizing production and reserves from offshore heavy oil fields using seismic and drilling technology: Alba and Captain Fields, UKNS

John Hampson

Skip Walden

Charles L. Bell

Abstract: Chevron North Sea Limited operates Alba and Captain, two large, mature, heavy oil fields in blocks 16/26 and 13/22a of the UK sector of the North Sea, respectively. Although the fields are structurally and stratigraphically different, their development schemes have been similar. Common components to both fields are that they are marine sandstone reservoirs; have one steel jacket, plus subsea templates; are under water injection for pressure support; utilize long horizontal development wells; use pilot holes an… Show more

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Cited by 3 publications

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The Alba Field, Block 16/26a, UK North Sea

Moore¹,

Archer²,

Peavot³

2020

Memoirs

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The Alba Field is a relatively heavy oil accumulation lying in an Eocene deep-water channel complex in Block 16/26a of the Central North Sea. With an estimated 880 MMbbl in place, the reservoir is characterized by thick, high net/gross sands with excellent reservoir properties and rock physics favourable for seismic property detection. The field has been developed by horizontal production wells, with pressure support provided by seawater injectors. After 24 years of production, more than 427 MMbbl have been recovered.Over the course of the development, the results of development drilling and improved reservoir imaging from seismic have revealed greater reservoir complexity than anticipated at sanction. The highly irregular reservoir geometry is likely to reflect the internal stacking patterns of channel elements within the channel complex that are locally overprinted by post-depositional remobilization. This increased reservoir complexity has required more wells to effectively drain the expected volumes. Despite this, recovery has exceeded estimates from the initial field development plan, reflecting an extremely efficient waterflood. 4D seismic spectacularly images extensive sweep away from injectors and excellent reservoir connectivity. Throughout the development, the application of seismic technologies has been a key enabler for effective reservoir management and, looking forward, maximizing value.

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The Alba Field, Block 16/26a, UK North Sea

Moore¹,

Archer²,

Peavot³

2020

Memoirs

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Alba Field – how seismic technologies have influenced reservoir characterization and field development

Moore

2014

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As giant oil fields mature, the flow of results from development drilling and production history, as well as interpretations of new seismic data, provide an evolving view of in-place volumes, reservoir architecture and fluid movement through the reservoir. Often, such changes can trigger modifications to asset development plans and, together with economic conditions, revisions to estimates of ultimate recovery.The development of the Alba Field – a relatively heavy oil (19° API) accumulation lying in an Eocene deep-water channel complex in Block 16/26 of the UK's Central North Sea – has followed a similar pattern. With an estimated 900 mmbbl of oil in place, the reservoir is characterized by thick, high net-to-gross (NTG) sands with extremely favourable reservoir properties. Because of the less favourable mobility ratio, Alba has been developed exclusively by horizontal production wells, with pressure support provided by a series of seawater injectors.By mid-2012, after 18 years of production, more than 390 mmbbl of oil had been recovered. During production, several key seismic and drilling technologies were applied to address reservoir complexities and reservoir management concerns that emerged as field development progressed. The most significant of these include the following: a dramatic uplift in imaging the depositional architecture was provided by converted shear wave seismic data (1998), revealing an extremely irregular top reservoir and hinting at greater internal complexity than initially modelled;advances in extended reach drilling technology enabled a greater number of infill targets to be accessed, while geosteering techniques allowed better well placement, and horizontal completions using gravel packs improved well reliability;spectacular images of production cones beneath horizontal production wells extracted from a dedicated 4D monitor survey (2008) addressed the field's key dynamic uncertainty – where is the remaining oil?A challenge for Alba has been to fully understand a 4D seismic signal that originates from long horizontal producers where vertical rather than lateral sweep dominates. Ultimately, reliable reservoir models that capture these valuable dynamic insights, based on geologically reasonable interpretations, will be the key tool that enables bypassed oil to be targeted and recovered, as fields such as Alba advance towards their development vision.

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Lower Cretaceous reservoir development in the North Sea Central Graben, and potential analogue settings in the Southern Permian Basin and South Viking Graben

Zwaan

2018

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Much of the future hydrocarbon exploration potential in the North Sea lies in locating stratigraphic traps and discrete reservoir intervals. This study assesses the potential for Lower Cretaceous reservoirs, with particular focus on the Norwegian Central Graben and proposed methods to identify future prospects over a wider area. Seismic interpretation and well data reveal the structure and sedimentology of the study area. Although the region was isolated from a large hinterland in the Early Cretaceous, potential local sediment sources, sediment transport routes and areas with possible reservoir development are identified. The greater Mandal High area, where Lower Cretaceous shoreface deposits and submarine fan systems are postulated, is suggested for primary focus. Similar deposits may have developed around the other exposed highs in the region, although several were drowned towards the end of the Early Cretaceous. Detailed seismic and stratigraphic analysis will be necessary to identify individual reservoir units. Since similar settings may have occurred in the adjacent South Viking Graben and Southern Permian Basin regions during the Early Cretaceous, further reservoir assessment is recommended for the North Sea in general.

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Maximizing production and reserves from offshore heavy oil fields using seismic and drilling technology: Alba and Captain Fields, UKNS

Cited by 3 publications

References 6 publications

The Alba Field, Block 16/26a, UK North Sea

The Alba Field, Block 16/26a, UK North Sea

Alba Field – how seismic technologies have influenced reservoir characterization and field development

Lower Cretaceous reservoir development in the North Sea Central Graben, and potential analogue settings in the Southern Permian Basin and South Viking Graben

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