An evaluation of pore pressure diffusion into a shale overburden and sideburden induced by production-related changes in reservoir fluid pressure

Ricard, Ludovic; MacBeth, Colin; HajNasser, Yesser; Schutjens, Peter

doi:10.1088/1742-2132/9/3/345

Cited by 4 publications

(1 citation statement)

References 22 publications

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“…The study of poroelastic response to fluid injection/extraction in underground reservoirs, and in particular of the pore-pressure diffusion, is usually performed using either analytical, semi-analytical or numerical approaches (e.g. Wang & Kümpel 2003;Ricard et al 2012;Altmann et al 2010Altmann et al , 2014Chang & Segall 2016, 2017Goebel et al 2017).…”

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Poroelastic model in a vertically sealed gas storage: a case study from cyclic injection/production in a carbonate aquifer

Silverii

Maccaferri

Richter

et al. 2021

Geophysical Journal International

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Summary Natural gas can be temporarily stored in a variety of underground facilities, such as depleted gas and oil fields, natural aquifers, and caverns in salt rocks. Being extensively monitored during operations, these systems provide a favorable opportunity to investigate how pressure varies in time and space and possibly induces/triggers earthquakes on nearby faults. Elaborate and detailed numerical modeling techniques are often applied to study gas reservoirs. Here we show the possibilities and discuss the limitations of a flexible and easily formulated tool that can be straightforwardly applied to simulate temporal pore-pressure variations and study the relation with recorded microseismic events. We use the software POEL (POroELastic diffusion and deformation) which computes the poroelastic response to fluid injection/extraction in a horizontally layered poroelastic structure. We further develop its application to address the presence of vertical impermeable faults bounding the reservoir and of multiple injection/extraction sources. Exploiting available information on the reservoir geometry and physical parameters, and records of injection/extraction rates for a gas reservoir in southern Europe, we perform an extensive parametric study considering different model configurations. Comparing modeled spatiotemporal pore-pressure variations with in situ measurements, we show that the inclusion of vertical impermeable faults provides an improvement in reproducing the observations and results in pore-pressure accumulation near the faults and in a variation of the temporal pore-pressure diffusion pattern. To study the relation between gas storage activity and recorded local microseismicity, we applied different seismicity models based on the estimated pore-pressure distribution. This analysis helps to understand the spatial distribution of seismicity and its temporal modulation. The results show that the observed microseismicity could be partly linked to the storage activity, but the contribution of tectonic background seismicity cannot be excluded.

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confidence: 99%

Poroelastic model in a vertically sealed gas storage: a case study from cyclic injection/production in a carbonate aquifer

Silverii

Maccaferri

Richter

et al. 2021

Geophysical Journal International

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The role of shale pressure diffusion in 4D seismic reservoir monitoring – case studies

Rangel¹,

MacBeth²

2015

SEG Technical Program Expanded Abstracts 2015

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Fluid Compositional Prediction in Conventional and Unconventional Petroleum Systems

Horsfield

Primio

2014

SPE Unconventional Resources Conference

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In conventional petroleum systems, predicting gas-oil ratio and charge volumes ahead of drilling is a proven element of exploration strategy. In shale plays the liquid-gas cut-off must be known precisely, and production from the liquid-prone zone optimised. In-place does not necessarily correspond to produced GOR. In particular the transition from volatile oil, to condensate to wet gas is crucial, and production strategies must be developed accordingly. The first step in unravelling the fractionation phenomena occurring in both play types is to determine the bulk composition of the petroleum that is first-formed in the source rock. This is because all subsequent processes simply act upon and modify this original composition. Here we present numerous case studies where PhaseKinetics (di Primio and Horsfield, 2006), a compositional kinetic approach for predicting in-situ bulk fluid properties, has been employed in appraising acreage, and then go on to consider some of the critical aspects surrounding unconventional plays. In high pressure-high temperature (HPHT) reservoirs of the North Sea, which can be considered closed systems, black to light oil GOR distributions in the North Sea Viking Graben closely matched the predictions from our MSSV pyrolysis experiments (method of Horsfield et al., 1989) performed on the Draupne Formation source rock (di Primio and Skeie, 2004). In a similar study of the Jade and Judy Fields in the Central Graben (di Primio and Neumann, 2008), GOR predictions from MSSV pyrolysis bore a close resemblance to the natural HPHT system. Other examples of excellent GOR predictive capability are provided by modelling the Egret Shale and its generated petroleum in the Jeanne d'Arc Basin, Canada (Baur et al., 2012), and the Bakken Shale and its petroleums in the Williston Basin, USA (Kuhn et al., 2010, 2012). The lessons learned from conventional systems about petroleum compositional predictions can be readily applied to shale resource plays. Of key importance is the structure of the precursor organic matter, determined by organofacies and maturity. This applies both vertically and laterally. We also draw attention to the importance of determining whether cumulative or instantaneous fluids are found within the range of pore sizes present in shale. In the mid- to late oil window, instantaneous fluids from the Posidonia Shale are rich in gas and light liquids; phase envelopes change rapidly with increasing maturity. Cumulative fluids in juxtaposed strata have lower GORs. Fracking has to take these points into account or production GOR might turn out to be quite different to in-situ GOR, a phenomenon that has already been noted for the Eagle Ford.

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An evaluation of pore pressure diffusion into a shale overburden and sideburden induced by production-related changes in reservoir fluid pressure

Cited by 4 publications

References 22 publications

Poroelastic model in a vertically sealed gas storage: a case study from cyclic injection/production in a carbonate aquifer

Poroelastic model in a vertically sealed gas storage: a case study from cyclic injection/production in a carbonate aquifer

The role of shale pressure diffusion in 4D seismic reservoir monitoring – case studies

Fluid Compositional Prediction in Conventional and Unconventional Petroleum Systems

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