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Coffee Break - 15 min Panel 1 - Making CO2 storage projects commercially feasible: CCS project alone is a huge CAPEX. What technical options do we have for vertical integration to offset the costs? Panel 2 - Risk Management in CO2 storage projects: What can go wrong from capture to storage and what options we have to control? An Overview of Occidental's Projects, Geophysical Technologies, Keynote and Challenges Seismic Inversion to reduce uncertainties in a Central Oman saline 9:40 0:20:00 10:00 Fadi Aljiroudi
- Asia > Middle East > Oman (0.26)
- Asia > Middle East > UAE (0.20)
- Asia > Middle East > Saudi Arabia (0.17)
- Geophysics > Seismic Surveying > Passive Seismic Surveying (0.49)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.35)
- Geophysics > Time-Lapse Surveying > Time-Lapse Seismic Surveying (0.34)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying > Vertical Seismic Profile (VSP) (0.30)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government (0.35)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Health, Safety, Environment & Sustainability > Environment > Climate change (1.00)
Abstract Most reported carbon storage projects have involved inexpensive CO2 capture from gas processing plants or ethanol refineries. However, widespread carbon capture and storage application must avoid any risk that high capital investment cost for carbon capture from stationary point sources leads to unanticipated issues related to the aquifer storage. This paper reviews successful and unsuccessful carbon storage projects and explains simple extended aquifer system fundamentals that must be considered in selecting a storage aquifer. This study begins by evaluating reported carbon storage projects in the context of an extended aquifer system with specific attention to initial formation pore pressure and potential or known hydraulic vertical or lateral communication with hydrocarbon accumulations and/or fresh water. Further study focusses on how the contrast between injection well and aquifer pressure evolution enables understanding of the overall aquifer material balance. Finally, we consider implications of brine migration during and after long term CO2 injection in unconfined aquifers. Experience in the petroleum industry with aquifer behavior include presence or lack of water influx and production from hydrocarbon reservoirs that share a common aquifer. Of particular importance is the observation that hydrostatic initial formation pressure indicates the possibility that a petroleum system, or an extended aquifer system without hydrocarbon accumulation(s), connects to atmospheric pressure through an unconfined aquifer. In such cases indefinite injection will never increase the regional aquifer pressure. Further, initial formation pressure that exceeds hydrostatic pressure implies a petroleum system or an extended aquifer system that is volumetrically limited. In such cases injection will increase the system pressure, and pressure monitoring can detect leakage from the system. Finally, CO2 injection into an aquifer will displace brine in the direction of lower pressure that could relate to distant production from the same aquifer or from hydrocarbon reservoirs with which it communicates. Reasons for known carbon storage project interruptions have included unexpected lateral plume migration or aquifer pressure increase during CO2 injection that might have been anticipated with attention to straightforward consideration of aquifer enabled hydraulic communication. Such extended aquifer dynamics must be included in long term models for permanent CO2 storage during and after injection.
- North America > United States (1.00)
- Europe > Norway > Barents Sea (0.93)
- North America > Canada > Alberta (0.68)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.47)
- North America > United States > Kentucky > Illinois Basin (0.99)
- North America > United States > Indiana > Illinois Basin (0.99)
- North America > United States > Illinois > Illinois Basin (0.99)
- (84 more...)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
Seismic characterization of CO2 storage driven by time-lapse images of a prior injection using the artificial neural network
Aldakheel, Mohammed (Curtin University, Saudi Arabian Oil Company) | Pevzner, Roman (Curtin University) | Gurevich, Boris (Curtin University) | Glubokovskikh, Stanislav (Curtin University, Lawrence Berkeley National Laboratory)
Abstract To optimize geologic CO2 storage and ensure its safety, it is necessary to demonstrate conformance between the reservoir simulations and geophysical monitoring such as time-lapse (TL) seismic. This process, known as history matching, often relies on subjective judgment and intuition of a reservoir modeling team because a direct examination of the multitude of plausible geologic scenarios is prohibitively expensive. The artificial neural network (ANN) aims to reconstruct the observed plume based on a set of seismic attribute maps. Via a randomized test, the trained model then provides an estimate of the importance of each attribute according to the attribute’s contribution to the accuracy of the plume prediction. This same test is also used to identify specific geologic controls for each part of the CO2 plume. The developed ANN is then used to forecast a CO2 plume that will likely arise from a future injection into the same formation 700 m away from the previous injection. The predicted map of the probability of the occurrence of CO2 after the future injection looks reasonable and agrees with existing reservoir simulations. At the same time, the neural network predicts some potential risks (e.g., across the fault migration) that were not considered in the fluid flow simulations. Although the neural network cannot fully replace high-fidelity fluid flow simulations, it can highlight geologic and petrophysical scenarios that should be simulated. Hence, our workflow may significantly improve the efficiency and accuracy of manual history matching.
- North America > United States > Texas (0.28)
- Asia > Middle East > Saudi Arabia (0.28)
- Geology > Geological Subdiscipline (0.93)
- Geology > Structural Geology > Fault (0.88)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.46)
- Oceania > Australia > Victoria > Otway Basin (0.99)
- Oceania > Australia > South Australia > Otway Basin (0.99)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Serbin Field (0.99)
- North America > United States > Mississippi > Cranfield Field (0.99)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- (2 more...)