Abstract:Calibration is a necessary step in the workflow for prediction of fault seal because there is no direct way to detect the hydraulic behaviour of a fault at the scale of a hydrocarbon trap. Over the last 20 years two general approaches have been developed:
Measurement of hydraulic properties of fault-zone samples (lab calibration), then mapping these results onto the appropriate parts of trap-bounding faults.Design of simple algorithms which attempt to capture a salient feature of the fault zone (e.g. CSP, SSF,… Show more
“…Fault reactivation and slip could have resulted from elevated pore pressures due to the increase of the hydrocarbon column height during gas expansion, oscillations in pressure due to ice loading-unloading and the overall fault orientation to the maximum horizontal stress field, S Hmax [13,72,73] and the characteristics of fault damage zones [63,74]. Additionally, gas cap expansion due to overburden removal by erosion would contribute to elevated pressures [11,75], enhancing the likelihood of fault slip and increase in permeability.…”
Hydrocarbon prospectivity in the Greater Barents Sea remains enigmatic as gas discoveries have dominated over oil in the past three decades. Numerous hydrocarbon-related fluid flow anomalies in the area indicate leakage and redistribution of petroleum in the subsurface. Many questions remain unanswered regarding the geological driving factors for leakage from the reservoirs and the response of deep petroleum reservoirs to the Cenozoic exhumation and the Pliocene-Pleistocene glaciations. Based on 2D and 3D seismic data interpretation, we constructed a basin-scale regional 3D petroleum systems model for the Hammerfest Basin (1 km × 1 km grid spacing). A higher resolution model (200 m × 200 m grid spacing) for the Snøhvit and Albatross fields was then nested in the regional model to further our understanding of the subsurface development over geological time. We tested the sensitivity of the modeled petroleum leakage by including and varying fault properties as a function of burial and erosion, namely fault capillary entry pressures and permeability during glacial cycles. In this study, we find that the greatest mass lost from the Jurassic reservoirs occurs during ice unloading, which accounts for a 60-80% reduction of initial accumulated mass in the reservoirs. Subsequent leakage events show a stepwise decrease of 7-25% of the remaining mass from the reservoirs. The latest episode of hydrocarbon leakage occurred following the Last Glacial Maximum (LGM) when differential loading of Quaternary strata resulted in reservoir tilt and spill. The first modeled hydrocarbon leakage event coincides with a major fluid venting episode at the time of a major Upper Regional angular Unconformity (URU,~0.8 Ma), evidenced by an abundance of pockmarks at this stratigraphic interval. Our modelling results show that leakage along the faults bounding the reservoir is the dominant mechanism for hydrocarbon leakage and is in agreement with observed shallow gas leakage indicators of gas chimneys, pockmarks and fluid escape pipes. We propose a conceptual model where leaked thermogenic gases from the reservoir were also locked in gas hydrate deposits beneath the base of the glacier during glaciations of the Hammerfest Basin and decomposed rapidly during subsequent deglaciation, forming pockmarks and fluid escape pipes. This is the first study to our knowledge to integrate petroleum systems modelling with seismic mapping of hydrocarbon leakage indicators for a holistic numerical model of the subsurface geology, thus closing the gap between the seismic mapping of fluid flow events and the geological history of the area.
“…Fault reactivation and slip could have resulted from elevated pore pressures due to the increase of the hydrocarbon column height during gas expansion, oscillations in pressure due to ice loading-unloading and the overall fault orientation to the maximum horizontal stress field, S Hmax [13,72,73] and the characteristics of fault damage zones [63,74]. Additionally, gas cap expansion due to overburden removal by erosion would contribute to elevated pressures [11,75], enhancing the likelihood of fault slip and increase in permeability.…”
Hydrocarbon prospectivity in the Greater Barents Sea remains enigmatic as gas discoveries have dominated over oil in the past three decades. Numerous hydrocarbon-related fluid flow anomalies in the area indicate leakage and redistribution of petroleum in the subsurface. Many questions remain unanswered regarding the geological driving factors for leakage from the reservoirs and the response of deep petroleum reservoirs to the Cenozoic exhumation and the Pliocene-Pleistocene glaciations. Based on 2D and 3D seismic data interpretation, we constructed a basin-scale regional 3D petroleum systems model for the Hammerfest Basin (1 km × 1 km grid spacing). A higher resolution model (200 m × 200 m grid spacing) for the Snøhvit and Albatross fields was then nested in the regional model to further our understanding of the subsurface development over geological time. We tested the sensitivity of the modeled petroleum leakage by including and varying fault properties as a function of burial and erosion, namely fault capillary entry pressures and permeability during glacial cycles. In this study, we find that the greatest mass lost from the Jurassic reservoirs occurs during ice unloading, which accounts for a 60-80% reduction of initial accumulated mass in the reservoirs. Subsequent leakage events show a stepwise decrease of 7-25% of the remaining mass from the reservoirs. The latest episode of hydrocarbon leakage occurred following the Last Glacial Maximum (LGM) when differential loading of Quaternary strata resulted in reservoir tilt and spill. The first modeled hydrocarbon leakage event coincides with a major fluid venting episode at the time of a major Upper Regional angular Unconformity (URU,~0.8 Ma), evidenced by an abundance of pockmarks at this stratigraphic interval. Our modelling results show that leakage along the faults bounding the reservoir is the dominant mechanism for hydrocarbon leakage and is in agreement with observed shallow gas leakage indicators of gas chimneys, pockmarks and fluid escape pipes. We propose a conceptual model where leaked thermogenic gases from the reservoir were also locked in gas hydrate deposits beneath the base of the glacier during glaciations of the Hammerfest Basin and decomposed rapidly during subsequent deglaciation, forming pockmarks and fluid escape pipes. This is the first study to our knowledge to integrate petroleum systems modelling with seismic mapping of hydrocarbon leakage indicators for a holistic numerical model of the subsurface geology, thus closing the gap between the seismic mapping of fluid flow events and the geological history of the area.
“…Different methodologies are also used for predicting fault sealing potential within sandstone/shale sequences (e.g., Bouvier et al, 1989;Antonellini and Aydin, 1994). One such methodology is based on the Shale Gouge Ratio (SGR; Yielding et al, 2010). This methodology uses the average clay content of the layers that have slipped past each other on the opposite side of a fault in order to evaluate fault-gouge composition (Fig.…”
a b s t r a c tWith developing countries strongly relying on fossil fuels for energy generation, geological carbon sequestration (GCS) is seen as a candidate for large reductions in CO 2 emissions during the next several decades. GCS does, however, raise some safety concerns. Specifically, it has been associated with induced seismicity, as a result of pressure buildup arising from prolonged CO 2 injection in GCS projects. This seismicity is a delicate issue for two main reasons. First, over a short time scale, deformation of rock could release seismic energy, potentially affecting surface structures or simply alarming the population, with negative consequences for the social acceptance of this kind of projects. Second, over a longer time scale, activated faults may provide preferential paths for CO 2 leakage out of reservoirs. While known major faults intersecting target aquifers can be identified and avoided during site screening, the same might not be true for faults that are not resolvable by geophysical surveys. In this study, we use geological observations and seismological theories to estimate the maximum magnitude of a seismic event that could be generated by a fault of limited dimensions. We then compare our estimate with results of geomechanical simulations that consider faults with different hydrodynamic and geomechanical characteristics. The coupled simulations confirm the notion that the tendency of faults to be reactivated by the pressure buildup is linked with the in situ stress field and its orientation relative to the fault. Small, active (critically stressed) faults are capable of generating sufficiently large events that could be felt on the surface, although they may not be the source of large earthquakes. Active, relatively permeable faults may be detrimental concerning the effectiveness of a storage project, meaning that they could be preferential pathway for upward CO 2 leakage, although minor faults may not intersect both CO 2 reservoirs and shallower potable aquifers.Published by Elsevier Ltd.
“…Strictly speaking, fault sealing as a property over the fault volume cannot be mapped directly with seismic. One rather looks at the impact of the fault on the surrounding rock (e.g., across fault pressure differences) to infer something about the fault properties and its sealing capacity (Yielding et al, 2010). A single fault surface with fault sealing properties determined in this manner is a reasonable estimate of the flow properties across and along the fault.…”
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