From basin modelling to basin management: reuse of basin-scale simulations

Skjervøy, Arild; Sylta, Øyvind; Weissenburger, Kate S.

doi:10.1016/s0928-8937(00)80014-4

Cited by 3 publications

(3 citation statements)

References 16 publications

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“…Major uncertainties exist concerning the directional, quantitative and qualitative aspects of secondary migration. From a review of previous studies, Skjervøy et al (2000) concluded that the main achievement of basin modelling is to have produced a reference framework which allows for continuous updating of existing models as more data become available. It is clear that the need for calibration points on basin-scale migration patterns is of great importance in this process.…”

Section: Modelling Hydrocarbon Generation and Expulsionmentioning

confidence: 99%

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Petroleum Migration, Faults and Overpressure, Part I: Calibrating Basin Modelling Using Petroleum in Traps - A Review

Karlsen¹,

Skeie²

2006

J Petroleum Geol

108

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the existence of oil or gas in both present-day and palaeo-accumulations of petroleum.Trapped petroleum represents an excellent source of information about hydrocarbon generation, expulsion, migration and accumulation, and the analysis of reservoired petroleum is a key tool in hydrocarbon exploration. Most geological information relates to the static rock framework, but oil which has moved through rock strata contains within it unique information for example on carrier interconnectivity and migration directions. Migrated petroleum also provides information on both source rock facies and temperatures of maturation and expulsion. In addition, physical changes which affected the petroleum during the migration process are preserved as geochemical "fingerprints"; these changes can be interpreted in terms of the mixing of different petroleums in a trap, leakage from the trap, biodegradation and mode of migration. Most processes affecting petroleum during migration and in a trap, whether they are biochemical, physical or This paper considers the principles of deciphering basin-scale hydrocarbon migration patterns using the geochemical information which is present in trapped petroleum. Petroleum accumulations in subsiding basins can be thought of as "data archives" within which stored information can help us to understand aspects of hydrocarbon formation and migration. This information can impart a time-resolved picture of hydrocarbon migration in a basin in response to processes associated with progressive burial, particularly in the context of the occurrence and periodic activity of faults.This review, which includes a series of tentative models of migration-related processes in the extensional Halten Terrace area, offshore mid-Norway, illustrates how we can use information from the migrating mobile hydrocarbon phase to improve our knowledge of the static geological system. Of particular importance is the role of sub-seismic heterogeneities and faults in controlling migration processes. We focus on how the secondary migration process can be enhanced in a multi-source rock basin such as the Halten Terrace, thereby increasing prospectivity.

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Section: Modelling Hydrocarbon Generation and Expulsionmentioning

confidence: 99%

“…These elements can be difficult, if not impossible, to decipher using basin modelling (cf. Skjervøy et al, 2000), as the basin and hence the flow patterns are constantly being modified.…”

Section: Introductionmentioning

confidence: 99%

Petroleum Migration, Faults and Overpressure, Part I: Calibrating Basin Modelling Using Petroleum in Traps - A Review

Karlsen¹,

Skeie²

2006

J Petroleum Geol

108

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“…The modelling of Skjervøy & Sylta (1993) predicted a deeper prospect that contained gas and a shallower prospect that contained gas with an oil leg. The later drilled wells (wells 30/8-1S, 30/5-2 and 30/8-3) showed similarities between the observed and modelled hydrocarbon columns (Skjervøy et al 2000). In this study, we have tried to investigate how increase and distribution of pressure influence hydrocarbon migration.…”

Section: Hydrocarbon Migrationmentioning

confidence: 98%

Influence of fault map resolution on pore pressure distribution and secondary hydrocarbon migration; Tune area, North Sea

Lothe¹,

Sylta²,

Lauvrak³

et al. 2006

Geofluids

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Pressure and hydrocarbon migration modelling was carried out in the Tune Field area, Viking Graben, offshore Norway. The pressures are considered to be controlled by compartments bounded by mapped faults. Two different interpreted fault maps at the top reservoir level (Brent Group) are used as input to the modelling. First, a low-resolution fault map is used, with only the large faults interpreted, and next, both large and small faults are included. The simulations show high overpressures generated in the western area, in the deeper part of the Viking Graben, and hydrostatic in the eastern areas. A sharp transition zone results from using the low-resolution fault map in the simulations. Small N-S striking faults situated in between the wells have to have higher sealing capacity than expected from juxtaposition analysis alone, to be able to match the overpressures measured in well 30/5-2 and 30/8-1S in the Tune Field, and well 30/8-3 east of Tune. The intermediate pressure in the western part is probably related to flow in the deeper parts of the sedimentary column in the compartment, where well 30/8-3 is situated. The secondary oil migration models show that overpressures have major effects on the migration pathways of hydrocarbons. The level of detail in the fault interpretation is important for simulation results, both for pressure distribution and for hydrocarbon migration.

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Estimation of oil and gas column heights in prospects using probabilistic basin modelling methods

Sylta

Krokstad²

2003

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Source rock and reservoir rock properties are often poorly constrained in the exploration for oil and gas. Geological analogues may be used to create source rock and reservoir rock models in areas with only sparse well data coverage. Exploration risks are often influenced by uncertainties in the rock facies models. This paper outlines a methodology for assessing the consequences of using two or more source and reservoir models on hydrocarbon phase distributions in prospects. Each source rock and reservoir rock scenario is represented by computerized maps (grids) of thickness, porosities and other properties. The uncertainties of each scenario are described using probabilistic properties. The reservoir thickness may be represented by a uniform distribution with the mean described using a map (grid) with a standard deviation of, for example, 50 m. A Monte Carlo simulation is carried out for this part of the petroleum system and the resulting probabilities of oil and gas in prospects are compiled by weighting each run to calibration wells. The results can be plotted as a map of most likely oil and gas column heights. An uncertainty map is also plotted. The results can be used to rank drilling locations with respect to large oil columns and low uncertainties. The oil and gas column probabilities can be estimated for each well location. As (more) wells are drilled within a petroleum system the best match simulations can be used to further refine predictions as well as to create an updated map of the petroleum system.

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From basin modelling to basin management: reuse of basin-scale simulations

Cited by 3 publications

References 16 publications

Petroleum Migration, Faults and Overpressure, Part I: Calibrating Basin Modelling Using Petroleum in Traps - A Review

Petroleum Migration, Faults and Overpressure, Part I: Calibrating Basin Modelling Using Petroleum in Traps - A Review

Influence of fault map resolution on pore pressure distribution and secondary hydrocarbon migration; Tune area, North Sea

Estimation of oil and gas column heights in prospects using probabilistic basin modelling methods

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