Integration of seismic methods with reservoir simulation, Pikes Peak heavy-oil field, Saskatchewan

Zou, Youlan; Bentley, L. R.; Lines, Larry; Coombe, D.

doi:10.1190/1.2210076

Cited by 13 publications

(5 citation statements)

References 14 publications

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“…This allows an earth model to be assembled, and the geomechanics model will be based on the use of seismics to interpolate between wells. To avoid excessive model complexity, usually a limited number of GMUs are defined (6)(7)(8)(9)(10)(11)(12)(13)(14)(15)(16)(17)(18)(19)(20), and usually these are chosen to correspond as well with clear lithostratigraphic units. In each GMU, a set of identical mechanical and petrophysical parameters is usually stipulated (although stochastic simulation can be used to vary parameters to simulate heterogeneity at various scales).…”

Section: Seismics and The Geomechanics Whole Earth Modelmentioning

confidence: 99%

Monitoring and Modelling in Coupled Geomechanics Processes

Dusseault¹

2007

Canadian International Petroleum Conference

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Geomechanics issues are vital in all reservoir processes, but particularly so in weak, unconsolidated sandstones. Coupled stress-flow simulation is necessary to analyse and understand effects such as changes in reservoir volume that arise from heating and pressurization, and non-linear plasticity models that incorporate shear dilatancy are needed to simulate the dilation effects that are observed in any thermal process in sands.Coupling of flow and stress is based on the volume changes that arise with changes in pressur and temperature. Incorporating shear dilation is based on computation of effective stresses from ΔT and Δp, then assessing the state of the rock to see if and how much it shears and dilates. These processes are ill-quantified at present, so it is necessary to monitor.The two monitoring domains that are of greatest interest to coupled geomechanics simulation are the deformation field and the seismic attributes field. More specifically, how these fields evolve in space and with time are the key factors to tracking processes to calibrating geomechanics models, and to the successful optimization of complex in situ processes.A general geomechanics view of how to achieve process monitoring and optimization goals is presented in a general fashion. Further progress in the areas of monitoring, inversion, and geomechanics simulation is needed, although recent developments have advanced these aspects.

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Section: Seismics and The Geomechanics Whole Earth Modelmentioning

confidence: 99%

Monitoring and Modelling in Coupled Geomechanics Processes

Dusseault¹

2007

Canadian International Petroleum Conference

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“…Integrating geologic, geophysical, and petrophysical data into one complete model of the whole field is an important process to help better understand the complexity of reservoir formations, thereby facilitating significant gains in productivity in terms of identifying and managing reservoirs (Zou et al, 2006;Denney, 2013;Adeoti et al, 2014). It provides reservoir engineers with a reliable and comprehensive basis upon which they can simulate and manage reservoirs (Al-Harbi et al, 2013;Karamitopoulos et al, 2013).…”

Section: Introductionmentioning

confidence: 99%

Integrated geologic, geophysical, and petrophysical data to construct full field geologic model of Cambrian-Ordovician and Upper Cretaceous reservoir formations, Central Western Sirte Basin, Libya

et al. 2019

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The Cambrian-Ordovician and Upper Cretaceous formations, which are the main oil-producing formations in the central Sirte Basin, are structurally complex. The lateral and vertical heterogeneity of the reservoir formations is not well-understood, which negatively affects the performance of the reservoirs. We constructed efficient full-field static models that incorporate the lateral and vertical variation of those reservoir formations by integrating geologic and geophysical data. We determined lithology and reservoir properties by selecting appropriate petrophysical techniques that suit the available well data and overcome issues with unreliable well-log measurements. In the process of building structural models, defining and mapping the base of the Cambrian-Ordovician Gargaf Formation was very challenging because wells did not penetrate the basal formation, and the quality of the seismic data decreases with depth. Therefore, we applied techniques of adding isochore maps of the overlying Upper Cretaceous of the Bahi and Waha Formations to map basal contact and determine the thickness of the Gargaf Formation for the first time in the area. The constructed isochore maps showed the thickness variation and the distributions of the Bahi and Waha Formations and explained the influence of Gargaf paleotopography and faults on them. The fault models combined with facies and property models suggested an interconnection among the three main reservoirs. They also indicated that the quality of the Waha reservoir enhances as the lithology varies from limestones to calcareous sandstones, whereas the quality of the Gargaf reservoir was primarily controlled by fractures. The total estimate of the original oil in place with the largest contribution of hydrocarbon volume from the Waha Formation was [Formula: see text] stock tank barrel. The created model with a fine-scale geocellular covering an area of [Formula: see text] is unique to the study area and it can be updated and refined at any time with new data production and drilling activities.

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“…Many authors have worked on the integration of 422 C 2014 European Association of Geoscientists & Engineers seismic time-lapse data in the simulation of conventional reservoirs (Huang, Meister and Workman 1997;Arenas, Oldenziel and Van kruijsdijk 2001;Gosselin et al 2003;Mezghani, Langlais and Lucet 2004;Caers, Strebelle and Wen 2006;Zou, Bentley and Lines 2006;Kazemi and Stephen 2008). Limited seismic timelapse monitoring can take advantage of abundant well production history data to interpret effectively the course of reservoir production.…”

Section: Introductionmentioning

confidence: 99%

“…Limited seismic timelapse monitoring can take advantage of abundant well production history data to interpret effectively the course of reservoir production. Many authors have worked on the integration of seismic time-lapse data in the simulation of conventional reservoirs (Huang, Meister and Workman 1997;Arenas, Oldenziel and Van kruijsdijk 2001;Gosselin et al 2003;Mezghani, Langlais and Lucet 2004;Caers, Strebelle and Wen 2006;Zou, Bentley and Lines 2006;Kazemi and Stephen 2008). This integration is ultimately intended to alleviate the non-uniqueness problem in the history matching of fluid-flow simulation.…”

Section: Introductionmentioning

confidence: 99%

Effect of oil composition on fluid substitution in heavy oil reservoirs

Shamsa

Lines²

2014

Geophysical Prospecting

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Unlike light oils, heavy oils do not have a well‐established scheme for modelling elastic moduli from dynamic reservoir properties. One of the main challenges in the fluid substitution of heavy oils is their viscoelastic nature, which is controlled by temperature, pressure, and fluid composition. Here, we develop a framework for fluid substitution modelling that is reliable yet practical for a wide range of cold and thermal recovery scenarios in producing heavy oils and that takes into account the reservoir fluid composition, grounded on the effective‐medium theories for estimating elastic moduli of an oil–rock system. We investigate the effect of fluid composition variations on oil–rock elastic moduli with temperature changes. The fluid compositional behaviour is determined by flash calculations. Elastic moduli are then determined using the double‐porosity coherent potential approximation method and the calculated viscosity based on the fluid composition. An increase in temperature imposes two opposing mechanisms on the viscosity behaviour of a heavy‐oil sample: gas liberation, which tends to increase the viscosity, and melting, which decreases the viscosity. We demonstrate that melting dominates gas liberation, and as a result, the viscosity and, consequently, the shear modulus of the heavy oils always decrease with increasing temperature. Furthermore, it turns out that one can disregard the effects of gas in the solution when modelling the elastic moduli of heavy oils. Here, we compare oil–rock elastic moduli when the rock is saturated with fluids that have different viscosity levels. The objective is to characterize a unique relation between the temperature, the frequency, and the elastic moduli of an oil–rock system. We have proposed an approach that takes advantage of this relation to find the temperature and, consequently, the viscosity in different regions of the reservoir.

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Integration of seismic methods with reservoir simulation, Pikes Peak heavy-oil field, Saskatchewan

Cited by 13 publications

References 14 publications

Monitoring and Modelling in Coupled Geomechanics Processes

Monitoring and Modelling in Coupled Geomechanics Processes

Integrated geologic, geophysical, and petrophysical data to construct full field geologic model of Cambrian-Ordovician and Upper Cretaceous reservoir formations, Central Western Sirte Basin, Libya

Effect of oil composition on fluid substitution in heavy oil reservoirs

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