Alwyn North Brent East Panel: Detailed Reservoir Analysis To Improve Reservoir Management and Recovery

Montmayeur, Hugues; Rae, S.F.; Coombes, Trevor

doi:10.2118/25009-ms

Cited by 3 publications

(1 citation statement)

References 2 publications

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“…It was initially developed with six producers and four injectors. Later wells located in the Frontal Area of Brent East provided evidence for fault scarp degradation (1) . The products of degradation, including the generation of slumps and slides, occurred within parts of the Frontal Area following onset of Brent erosion at the structural crest in the latest part of the Upper Jurassic.…”

Section: Introductionmentioning

confidence: 99%

Optimising Performance of Mature Reservoir: An Innovative Use of Coiled Tubing Drilling Technology to Tap Unswept Reserves, Alwyn North UKCS

Lheure

Müller

Kimber

et al. 2000

Proceedings of SPE European Petroleum Conference

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThis paper describes the rationale, the planning and the preliminary results of the first Coiled Tubing Drilling (CTD) experience for TotalFina. The objective was to enhance production from a high water-cut oil well producing under unstable conditions and located in an area of possible upsides. This well was drilled in 1990 on the edge of a fault-scarp degradation complex in the Brent East panel of the Alwyn Field. The geological uncertainties in this complex area needed to be reduced and it was necessary to reassess seismic, core and reservoir data to progress the current knowledge base. Analytical calculations supported 3D reservoir modelling techniques to constrain some of the uncertainties.Drilled in 1999, well 3/9a-N30Y was the first coiled tubing sidetrack from a producing well on Alwyn. The motherbore, 3/9a-N30, was still producing around 380 stb/d, although production had recently become intermittent.The well path presented a challenging trajectory due to the location of the unswept area in relation to the direction of the motherbore. After drilling 240m a series of operational issues arose, necessitating the drilling of the world's deepest open hole sidetrack with coiled tubing, but ultimately the BHA was left in hole. The coiled tubing was then utilised as an uncemented liner, perforations using slim guns were added along the liner, and the well was brought onto production. The CTD drain alone produced at an initial rate of 2900 stb/d, which stabilised out at 1200 stb/d after an initial rise in water cut.The successful outcome of 3/9a-N30, which was drilled in a complex offshore environment, confirmed the viability of CTD as a technique for accessing smaller pockets of remaining oil, whilst some of the operational difficulties encountered highlighted the need to simplify future trajectories to maximize the chance of success. With the possibility of drilling future CTD wells, further increases in productivity and reserves will be achieved at a significantly lower cost compared to conventional drilling.

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Section: Introductionmentioning

confidence: 99%

Optimising Performance of Mature Reservoir: An Innovative Use of Coiled Tubing Drilling Technology to Tap Unswept Reserves, Alwyn North UKCS

Lheure

Müller

Kimber

et al. 2000

Proceedings of SPE European Petroleum Conference

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Impact of sequence-based correlation style on reservoir model behaviour, lower Brent Group, North Cormorant Field, UK North Sea

Wehr¹,

Brasher²

1996

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Experiences in Incorporating a 3D Geological Model into a Reservoir Simulator

Rae

Neve

1994

All Days

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SPE Members Abstract Advances in computing technology have allowed the development of sophisticated 3D cellular modelling and visualisation software which has found a variety of applications in the oil industry. This includes spatial attribute modelling and the visualisation of hydrocarbon reservoirs to improve the understanding of the geological structure including internal features, the distribution of formation properties and the movement of fluids once field production begins. This paper discusses experiences gained in building a geological 3D model of the West Flank of the Alwyn North reservoir and the subsequent manipulation and transfer of this data into a 3D reservoir simulator for initialisation. The techniques used differ considerably from the traditional method using 2D surface mapping packages. The advantages of both geoscientist and reservoir engineer being able to see and review the 3D image of the reservoir at an early stage in the project is discussed. The paper covers the modelling of the reservoir's complex heterogeneities, the handling of both vertical and sloping fault surfaces, deviated wells and the contrasts in the number of cells of the geological model compared with the number of blocks in the reservoir simulation model. Procedures for up-scaling from geological to reservoir model are discussed along with the errors introduced in the transfer of data and subsequent re-sampling by different software packages. The paper concludes with suggestions for future developments of software to further enhance this effective method of modelling. Introduction The Alwyn North Field is jointly owned by Total Oil Marine plc. (operator), 33.33% and Elf Exploration U.K. plc., 66.66%. The field lies in blocks ½a and 3/9a of the Northern Sector of the North Sea, (Figure 1). The field produces hydrocarbons from both the Brent and Statfjord sandstone reservoirs. The initial recoverable reserves are estimated to be 218 MMstb of oil and 27 GSm3 of gas. The field came onstream in November 1987 and by the end of September 1993 had produced 170 MMstb of oil and 16.1 GSm3 of gas. The field can thus be regarded to be at a mature stage in its development. Extensive 3D seismic coverage has delineated a series of westerly dipping fault blocks which show extensive erosion and slumping along the eastern edge. There are two principle fault directions, a major NNW-SSE trend and a secondary ENE-WSW transverse trend. This faulting has divided the Brent reservoir into a series of five hydrocarbon bearing panels as indicated in Figure 2. The three panels comprising Brent North West, Brent Central West and Brent South West are referred to collectively as the West Flank. Four separate reservoir models have been constructed to cover the Alwyn North field. These are the Statfjord model, the Brent East model, the Brent North model and the West Flank model. It is the construction of the latter model which is discussed in this paper. P. 263^

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Alwyn North Brent East Panel: Detailed Reservoir Analysis To Improve Reservoir Management and Recovery

Cited by 3 publications

References 2 publications

Optimising Performance of Mature Reservoir: An Innovative Use of Coiled Tubing Drilling Technology to Tap Unswept Reserves, Alwyn North UKCS

Optimising Performance of Mature Reservoir: An Innovative Use of Coiled Tubing Drilling Technology to Tap Unswept Reserves, Alwyn North UKCS

Impact of sequence-based correlation style on reservoir model behaviour, lower Brent Group, North Cormorant Field, UK North Sea

Experiences in Incorporating a 3D Geological Model into a Reservoir Simulator

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