The Nelson Field, Blocks 22/11, 22/6a, 22/7, 22/12a, UK North Sea

Kunka, J.; Williams, G.A.; Cullen, Brian; Boyd-Gorst, John; Dyer, George R.; Garnham, J.; Warnock, Andrew C.; Wardell, J.; Davis, Adam; Lynes, P.

doi:10.1144/gsl.mem.2003.020.01.50

Cited by 22 publications

(14 citation statements)

References 11 publications

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“…The incised material was transported basinwards and deposited as mass-transport deposits in the basal part of the main Forties Sandstone fairway. The interval is characterized in the Nelson Field by abundant reworking of older Lista Formation palynomorphs and associated organic material (Jennette et al 2000;Kunka et al 2003).…”

Section: T60 Sequence (Uppermost Lista Formation)mentioning

confidence: 99%

“…The Nelson (Whyat et al 1992;Kunka et al 2003), Forties (Wills 1991;, Montrose, Arbroath and Arkwright (Hogg 2003) fields are examples of channel-dominated reservoirs located along the west axial fairway. No large faults are observed in these fields, which have an anticlinal closure with a relief of up to 200 m resulting from the differential compaction of the underlying Jurassic claystone formations (Hill & Wood 1980).…”

Section: Channel-dominated Settingsmentioning

confidence: 99%

“…Gill & Shepherd 2010). Channel bank failures are common in such settings and can be a locally prominent component of the channel-fill (Hogg 2003;Kunka et al 2003;, leading to locally isolated (albeit relatively small) volumes.…”

Section: Channel-dominated Settingsmentioning

confidence: 99%

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Sedimentological evolution of Sele Formation deep-marine depositional systems of the Central North Sea

Eldrett

Tripsanas

Davis

et al. 2015

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The Paleocene -Eocene-aged Sele Formation is developed across the basinal region of the Central North Sea. The section comprises a number of deep-marine fan systems that expanded and contracted across the basin floor in response to relative sea-level changes on the basin margin and fluctuating sediment yield off the Scottish landmass modulated by climate and hinterland uplift. Persistent sediment entry points to the basin resulted in the development of discrete axial and transverse fan fairways with a geometry dictated by an irregular bathymetry sculpted by differential compaction across Mesozoic faults, halokinesis and antecedent fan systems. A high-resolution biostratigraphic framework has allowed the evolution of fan-dispersal systems in response to these effects to be tracked across the basin within four genetic sequences. The proximal parts of the fans comprised channel complexes of low sinuosity, high lateral offset, and low aggradation. The development of these systems in a bathymetrically confined corridor of the Central Graben (c. 65 km wide), combined with high sediment supply, resulted in the eventual burial of any underlying relief. The behaviour of sand-rich reservoirs in this region is dominated by the permeability contrast between high-quality channel fairways and more heterolithic overbank regions, with the potential for early water breakthrough and aquifer coning in the channel fairways, and unswept volumes in overbank locations. Compartmentalization of compensationally stacked channel bodies occurs locally, with stratigraphic trapping caused by lateral channel pinch-outs, channelbase debrites, mud-rich drapes and abandonment fines. Towards the southern part of Quadrant 22, approximately 150 km down-palaeoflow, the systems became less confined and in this region are dominated by channel-lobe complexes, which continued to interact with an irregular bathymetry controlled by antecedent fans, mass-transport complexes and halokinesis in the form of rising salt diapirs. Reservoirs in this region are inherently stratigraphically compartmentalized by their heterolithic lithology and compensational stacking of lobes, and further complicated by structuration and instability induced by the diapiric or basement structures needed to generate a trapping structure in these settings.The Sele S1 Unit contains the most areally extensive and thickest deep-water sandstone member of the Sele Formation, namely the Forties Sandstone Member (FSM). The FSM is restricted to the Central Graben, is over 200 m thick along reaches of the SELE FORMATION DEPOSITIONAL SYSTEMS J. ELDRETT ET AL.

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Section: T60 Sequence (Uppermost Lista Formation)mentioning

confidence: 99%

Section: Channel-dominated Settingsmentioning

confidence: 99%

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Sedimentological evolution of Sele Formation deep-marine depositional systems of the Central North Sea

Eldrett

Tripsanas

Davis

et al. 2015

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“…The Forties (Wills et al 1991) and Nelson fields (Kunka et al 2003) are supported by basal aquifers. The Arbroath field contains oil bearing sandstones which have a mudstone layer at their base (Crawford et al 1991) and can be considered to be edge aquifer supported.…”

Section: Aquifer Influxmentioning

confidence: 99%

Secondary Application of Low Salinity Waterflooding to Forties Sandstone Reservoirs

2014

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Low salinity waterflooding (LSWF), versus high salinity waterflooding (HSWF) has been the focus of significant research at various centres around the world, yet there is still considerable debate over the exact mechanism that provides incremental oil recovery. The use of the LSWF technique is not widespread in the United Kingdom continental shelf (UKCS). However, it has been announced that the Clair Ridge development will deploy low salinity waterflooding (LSWF) in secondary mode from the start of field life, and a number of companies are currently assessing the applicability of the technique through high level screening and core flooding. Forecasting the potential oil recovery under LSWF is heavily influenced by the simulation technique that is used. Presently the most widely discussed approach is the use of a weighting table with relative permeabilities representing the high and low salinity cases. As the grid block falls below threshold salinity, the simulator utilises the weighting table to assign an interpolated value of salinity. This value of salinity is utilised to represent a change in wettability. While this approach approximates the net effect of LSWF, it does not capture the oil/rock/brine interaction. This study examines the modelling approach to LSWF utilising an in-house generic Forties Palaeocene model in CMG's STARS simulator. The conventional approach of modelling LSWF using high and low salinity relative permeabilities is compared to the latest Multi-component Ion Exchange (MIE) methods by numerical simulation to assess the impact on incremental oil recovery. A sensitivity analysis is then carried out on the effects of specific parameters on incremental oil recovery, utilising published data from fields in the Forties Palaeocene fan system. A discussion is provided. The impact on secondary recovery was accessed with respect to wettability alteration; injection salinity (LSWF versus HSWF); oil viscosity and aquifer influx. The application of LSWF in secondary mode to the Forties Palaeocene Sandstones was found to be favourable for the case of mixed-wet reservoirs.

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“…cir. ), Mungo, Nelson (Wyatt et al 1992;Kunka et al 2003), Orion, Pierce (Birch & Haynes 2003) and Sedgewick fields (Fig. 42), which occur in a variety of play types (Fig.…”

Section: P a L A E O G E N Ementioning

confidence: 99%

The tectonic and stratigraphic framework of the United Kingdom's oil and gas fields

Underhill

2003

Memoirs

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Onshore exploration success during the first half of the 20th century led to petroleum production from many, relatively small oil and gas accumulations in areas like the East Midlands, North Yorkshire and Midland Valley of Scotland. Despite this, the notion that exploration of the United Kingdom's continental shelf (UKCS) might lead to the country having self-sufficiency in oil and gas production would have been viewed as extremely fanciful as recently as the late 1950s. Yet as we pass into the new century, only thirty-five years on from the drilling of the first offshore well, that is exactly the position Britain finds itself in. By 2001, around three million barrels of oil equivalent were being produced each day from 239 fields. The producing fields have a wide geographical distribution, occur in a number of discrete sedimentary basins and contain a wide spectrum of reservoirs that were originally deposited in diverse sedimentary and stratigraphic units ranging from Devonian to Eocene in age. Although carbonates are represented, the main producing horizons have primarily proved to be siliciclastic in nature and were deposited in environments ranging from aeolian and fluviatile continental red beds, coastal plain, nearshore beach and shelfal settings all the way through to deep-marine, submarine fan sediments. This chapter attempts to place each of the main producing fields into their proper stratigraphic, tectonic and sedimentological context in order to demonstrate how a wide variety of factors have successfully combined to produce each of the prospective petroleum play fairways and hence, make the UKCS such a prolific and important petroleum province.

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The Nelson Field, Blocks 22/11, 22/6a, 22/7, 22/12a, UK North Sea

Abstract: The Nelson Field is located in Blocks 22/11, 22/6a, 22/7 and 22/

Cited by 22 publications

References 11 publications

Sedimentological evolution of Sele Formation deep-marine depositional systems of the Central North Sea

Sedimentological evolution of Sele Formation deep-marine depositional systems of the Central North Sea

Secondary Application of Low Salinity Waterflooding to Forties Sandstone Reservoirs

The tectonic and stratigraphic framework of the United Kingdom's oil and gas fields

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