Third EAGE Conference on Carbon Capture and Storage Potential
- Conference date: August 12-13, 2024
- Location: Perth, Australia
- Published: 12 August 2024
1 - 20 of 39 results
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Unlocking the Offshore CCS Monitoring Puzzle: Time-lapse Gravity and Seafloor Deformation Surveys
More LessAuthors H. Ruiz and J.E. LindgardSummaryMonitoring strategies for offshore CCS cannot simply replicate those used in the oil and gas industry. Regulations mandate monitoring throughout the project’s entire lifespan, including decades post-closure. CCS calls for cost-effective solutions, making expensive high-resolution methods like seismic less viable. Moreover, environmental regulations pose challenges to the intensive use of seismic methods, that feature large CO2 footprints and active sources. Operationally, the presence of infrastructure like wind farms, hinders the systematic surveying patterns required for seismic monitoring. Last but not least, 4D seismic signal detectability can be low when CO2 is injected into depleted gas reservoirs due to the weak contrast with the preexisting residual gas. Time-lapse gravity and seafloor deformation monitoring is a mature commercial technology used for 25 years in Norway to fully replace or complement 4D seismic in gas-producing reservoirs. Recent modeling for CCS projects like Morecambe in the UK demonstrates very significant and robust time-lapse gravity signals after one year of injection, indicating an excellent capability to delineate both the CO2 and the pressure plumes. This offers a viable path forward for monitoring CO2 storage sites sustainably and cost-effectively, while overcoming the operational limitations of 4D seismic. This can be crucial for the long-term success and economic viability of CCS projects.
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Thermo-Chemo-Mechanical Models to Evaluate the Seismic Properties of Water-rock-CO2 Reactions for Carbon Sequestration in Fractured Reservoirs
More LessSummaryA typical reservoir for carbon capture and sequestration (CCS) consists of porous hydrous basalt formations with stiff and soft pores (cracks). Fe-and Ca-rich basalt formations are the most promising mafic reservoir where the dominant storage mechanism involves solubility and mineralization through water-rock-CO₂ reactions. Insights into the elasticity, porosity, and permeability of water-rock-CO₂ reactions have great potential for seismic monitoring in carbon sequestration, which remains largely unaddressed in the literature. Cements (carbonate nodules), growing around the edges of cracks/fractures, frequently block up fluid-flow pathways, significantly affecting permeability and consolidation. Based on double-porosity thermoelastic theory, we propose a thermo-chemo-mechanical model for water-rock-CO₂ reactions to estimate the carbon storage capacity of fractured reservoirs. Considering the permeability of soft cracks is affected by the radius of carbonate nodules, we estimate the P-wave velocity and the carbon amount sequestered after CO₂ injection.
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The Groundwater Hydrogeological Modeling for Site Selection of CO2 Injection, Example of the Kanto Plain, Japan
More LessAuthors Y. Ishise, T. Shimamoto, Y. Kobayashi, M. Yoshioka, R. Ikawa and I. MachidaSummarySaline aquifers are considered to be the major targets to inject CO2 for many Geological Carbon Storage (GCS) projects. To achieve public acceptance and to estimate CO2 storage capacity adequately, the comprehensive understanding of regional groundwater flows is important since groundwater flow eventually affects containment of injected CO2 and can relate boundary conditions in numerical CO2 flow simulation.
In this presentation, we present a case study of the regional groundwater hydrogeological modelling conducted for the Kanto Plain in Japan, where is selected as one of the potential candidates for large scale GCS projects by JOGMEC. This region is one of the largest depositional basins in Japan and encompasses the Tokyo metropolitan area where contains significant CO2 emission sources.
We first compiled and analyzed numerous kinds of published information around this area related to groundwater flow characteristics, including chemical properties. Subsequently, we built a comprehensive numerical simulation model being consistent with these data.
The results of our numerical simulation confirmed that the groundwater flow velocity in the lower Pleistocene and below formations is very low, several to ten millimeters per year, and in terms of groundwater flow, these formations are preferred for GCS in this area.
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Toward Reducing Uncertainty in Caprock Assessment: Insights from an Outcrop Analogue
More LessAuthors K. Nifuku, S. Watanuki, Y. Iijima, Y. Kobayashi and M. ItoSummaryUncertainty in caprock assessment is one of the concerns in geologic carbon storage. It is especially caused in an area where an available geological dataset is lacking or limited. In such a case, a detailed database from a geological analogue can be utilized to reduce the uncertainty. This study investigated spatial changes in seal capacity of mudstones from onshore outcrops of the Pleistocene Kazusa Group near the Tokyo Bay area, to establish a geological analogue of caprock property in an active margin sedimentary basin. Seal capacity of the mudstones shows a distinct decrease landward in a relatively short distance from lower-slope to shelf-margin deposits, whares it is the highest and nearly constant in the basin-floor deposits. The findings can be utilized as a geological analogue for the caprock assessment in subsurface successions of this sedimentary basin as well as in other sedimentary basins with similar geological settings, such as high sedimentation rates and siliciclastic-dominated sedimentary successions formed in active margins.
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ISO Certification to Provide Risk Assurance to CCS Projects
More LessAuthors D. Labregere and P. Van den BogertSummaryThe abstract highlights the significance of Carbon Capture and Storage (CCS) in mitigating CO2 emissions and its role in combating climate change amidst evolving legislative frameworks and technological challenges. It emphasizes the need for comprehensive risk assessment across various domains such as environmental, technical, operational, economic, political, and stakeholder aspects in the nascent stages of CCS projects. ISO 27914 serves as a pivotal international standard ensuring safe CO2 storage, offering assurance to stakeholders through rigorous risk-based practices. The abstract discusses the application of ISO certification in the entire lifecycle of CCS projects, focusing on site feasibility and storage certification processes. It elaborates on the subsurface requirements and recommendations, emphasizing the importance of addressing potential leakage pathways. Furthermore, it underscores the multidisciplinary approach required for subsurface characterization and modelling, highlighting the differences in mindset compared to conventional hydrocarbon projects. In summary, ISO certification is depicted as a trust-building mechanism for stakeholders, aiding governments, regulators, project partners, and funders in supporting CCS initiatives aimed at reducing CO2 emissions and combatting climate change.
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Active Seismic Monitoring of Geological Carbon Storage using Refracted Waves: Feasibility Study
More LessAuthors R. Pevzner, H. Nourollah and B. GurevichSummaryFor conformance monitoring (and, maybe, large leakage detection) in large-scale CO2 projects, it may be beneficial to use head waves refracted beneath the reservoir. We explore the feasibility of this approach through seismic modelling for a cartoon model of CarbonNet Pelican site. We also simulate a similar monitoring approach for a forthcoming shallow fault injection at the CO2CRC’s Otway site in the Australian State of Victoria. This experiment can be viewed as a scaled model for larger injections. Based on these modelling results, we provide a short overview of the further field experiments that can be used to validate the proposed approach.
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Dry Structures for CO2 Storage Site: A Quick-Look Assessment of Characteristics and Potential Utilization in SEA
More LessAuthors N.Z. Mat Razali, D. Ooi and A.J. DimabuyuSummaryDry structures refer to geological formations that were drilled but encountered oil and gas shows, or where existing wells seem to have encountered water instead. CO2 storage in dry structures has fewer issues with well integrity and offers more space, but it lacks proven geological and geophysical containment elements. This means additional information is also needed, like saline aquifer storage. This paper demonstrates the target area evaluation by integrating risk identification into the integral process for assessing CO2 storage prospects, specifically focusing dry structures in SEA. The primary objective of this study is to identify potential CO2 sources from both developed and undeveloped fields, and to pinpoint potential future storage candidates based on certain practices. Additionally, this paper aims to develop rapid screening criteria for assessing the suitability of dry structures as potential saline aquifer storage sites. Other than that, this research includes a comparative study between approved CCS projects and the identified dry structure storage sites. Utilizing the outlined methodology, numerous structures across diverse basins in the area have been pinpointed as potential candidates for future CO2 storage. Geological features like faults, stratigraphy, and hydrogeology serve as ideal considerations for characterizing site selection.
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Cost-efficient and Fit-for-purpose Monitoring using Surface Deployed Fiber Optics
More LessAuthors M. Branston and R. BachrachSummaryFiber-optic distributed acoustic sensing (DAS) technology is a technology that measures subsurface vibrations by probing the strain induced on a fiber-optic cable by an acoustic wavefield and has been demonstrated to provide a reliable alternative to traditional point receivers when deployed horizontally at surface (S-DAS). S-DAS, can record both P-wave (PP) and converted wave (PS) arrivals, is therefore well suited to monitoring CCS-related pressure and saturation changes when deployed in conjunction with a wider injection monitoring program. In recent years, we have demonstrated the significant potential of S-DAS imaging for both PP and PS wavefields. We report on our ability to image production-induced saturation changes and the potential to image production-based pressure changes, which provides valuable feedback in the early stages of the injection. We have demonstrated the key role S-DAS has to play as a low-cost seismic sensor, which can be interrogated over decades with no maintenance. Furthermore, through our novel acquisition geometry designs for S-DAS we also demonstrate its potential as a low impact, low acquisition footprint solution, lending itself to deployment in an adaptive manner, scaling the source effort to the phase of injection and monitoring objective; redefining the cost of seismic monitoring.
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Carbon Storage Screening Study of Southeast Asia: A Case Study from Offshore Sarawak
More LessAuthors E. Shepherd, S. Otto and G. DuvalSummarySoutheast Asia has become well-positioned as an emerging hotspot for Carbon Capture and Storage (CCS). Recent regulatory initiatives and public funding incentives are helping to kickstart CCS activity in the region. However, one of the biggest barriers facing CCS rollout in this region is the lack of information on the total availability of carbon storage resources, both onshore and offshore, and covering both depleted oil and gas fields and saline aquifers.
CGG’s Southeast Asia carbon storage screening study has evaluated 58 basins across Indonesia, Malaysia, Thailand, Vietnam and Brunei. For this, a 3-phase approach is used to exclude unsuitable basins, rank the remaining basins and finally, the highest scoring basins have their plays inventorized, mapped and ranked. To demonstrate the successful application of this methodology, a case study of one of the key basins analyzed will be presented (Offshore Sarawak Basin, Malaysia). Comparisons drawn between the Offshore Sarawak Basin, and other basins in the area, will also be discussed.
This screening study will help Southeast Asia realize its carbon storage potential in the near term and help accelerate the region’s CCS activities. In a transitional landscape where time is pressing, this will allow CO2 emissions pledges to be met sooner.
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CO2 Migration and Trapping Behavior in a Heterogeneous Media: Core- and Pore-scale Study
More LessSummaryUnderstanding the migration of CO2 and water in complex geologic media is crucial for ensuring the safety and long-term efficacy of CO2 geological storage. Geologic heterogeneity has a significant effect on multiphase flow properties as well as CO2 trapping mechanisms. This study investigates CO2 migration and trapping mechanisms in heterogeneous geological media utilizing X-ray imaging technique. Both the core- and pore-scale multiphase flow experiments were conducted using a sandstone with sedimentary lamination. At the core scale, capillary heterogeneities influenced CO2 displacement, with higher initial saturations widening the residual trapping distribution. New flow regimes during dissolution were identified, and a scaling relationship for their temporal evolution was proposed. Pore-scale analysis revealed micro-scale heterogeneities impacting CO2 flow dynamics, with spatial variation in capillary entry pressure leading to non-uniform flow. In-situ imaging captured CO2 cluster breakup and local imbibition processes. These findings enhance our understanding of multiphase flow in heterogeneous porous media, and our study underscores the importance of considering both core- and pore-scale heterogeneities for CO2 geological storage.
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The Impact of CO2 Saturated Brine on Petrophysical Properties of the Angel Storage Formation
More LessAuthors J. BrethertonSummaryPetrophysical interpretation and modelling plays a key role in assessing storage capacity, injectivity, sealing capacity and ongoing conformance monitoring for a CCS project. To understand any impact the introduction of pure CO2 saturated brine might have on the Angel storage formation petrophysical properties, 20 core plug samples capturing the range of petrophysical property groups representing the Angel storage formation underwent baseline petrophysical measurements. The plugs after static ageing in CO2 saturated brine for 20 and 40-days at in-situ reservoir conditions were re-tested and reimaged to evaluate the impact of static fluid-rock interactions on the petrophysical properties.
The results showed negligeable changes to porosity and a varying increase in permeability. Generally greater increases in permeability were associated with higher permeability samples. SEM images show evidence of pore throat scale microstructural differences and dissolution of reactive dolomitic cement. The study showed that no impairment to the Angel storage formation in place volume capacity would be expected with the introduction and long-term storage of CO2 at the planned injection site within the aquifer. Small scale improvement in permeability could occur at the injection site although this is not expected to propagate far into the formation during injection of CO2.
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Coupling Unified Ensemble Modelling with Invasion Percolation Simulation for Early Appreciation of Risk in CO2 Containment
More LessAuthors G. Williams, J. Mukherjee, S. Ducroux, A. Skorstad and A. OlariuSummaryDuring the initiation stages of CO2 storage projects, predicting the ultimate plume distribution presents a significant challenge due to the presence of substantial uncertainties in subsurface conditions. These uncertainties, when predicting plume distribution, need to be handled in a consistent way to better assess risks related to containment and to ultimately determine a storage site as having a low risk profile. This paper summarizes a method that utilizes ensemble-based approaches to create a range of realizations that represent uncertainty from the outset, to characterize uncertainties in static geomodels. A dynamic simulation is performed on each of these geomodel realizations using a modified invasion percolation simulator to improve model runtimes and deliver accurate representations of plume migration. The simulation outcomes are compared to known plume distributions to assess conceptual leakage risks. What we discovered was that even in a highly studied storage site with relatively low heterogeneity, our predictions remain highly sensitive to uncertainties. This underscores the need for robust assessment methods when evaluating new targets, regardless of how much we may think we already know.
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Storage Formation Modelling for CCS: Lessons Learnt from a Reservoir Case Study, Offshore Western Australia
More LessAuthors S. Thompson and J. LouisSummaryA key component to enable successful, large-scale deployment of CCS is the storage formation modelling process. The main objective for CCS storage formation modelling is to provide accurate insights in understanding capacity, containment and injectivity of the project to ensure safe, efficient and permanent CO2 storage. Storage formation modelling has been recently conducted for the Angel CCS Project – a proposed large scale multi-user CCS development aimed at facilitating decarbonisation in Western Australia. A number of key storage formation modelling lessons learnt were identified that may be applicable to other projects that intend to model hydrocarbon reservoirs for CCS purposes. These lessons include appropriate sizing of the storage formation model both spatially as well as vertically, utilizing existing legacy models or creating simple sector models for early and quick variable testing, calibrating models to existing regional datasets which may also include production data, and a change in mind set with regards to uncertainty characterisation and terminology from traditional hydrocarbon projects to a CCS specific projects.
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CO2-water-rock Reactions and Metal Mobilization: A CO2 Storage Demonstration Site in the Surat Basin
More LessAuthors J. Pearce, G. Dawson, D. Kirste, F. Brink, S. Golding, G. Southam, D. Paterson, N. Hall, R. Heath and D. GreerSummaryDemonstration scale CO2 geological storage has been proposed in the lower Precipice Sandstone, Surat Basin, Australia. The Evergreen Formation is the overlying seal (cap-rock), and the Moolayember Formation of the Bowen Basin the underlying formation (bottom seal). CTSCo has drilled several wells for feasibility studies. The potential for CO2-water-rock reactions to release metals to low salinity groundwater was a potential risk since the site is within the Great Artesian Basin. Metals were hosted in several minerals in the West Wandoan 1 well rock cores, with total concentrations higher in the Moolayember Formation and reservoir mudstones, than in the reservoir sandstones. Drill cores were reacted with supercritical CO2 or impure CO2-SO2-NO-O2 at in situ conditions. Minerals including calcite, ankerite, siderite, Fe-rich chlorite, and sulphides reacted. Dissolved Ca, Mn, Zn, Rb, etc. were released at variable concentrations dependant on the rock mineral content and gas stream. Fe and Pb generally increased initially, then decreased as Fe-oxyhydroxide minerals precipitated especially in the presence of O2. Carbonates were the main sources of metals as they dissolved more readily, with some release from ion exchange/desorption. Ultimately, a reactive transport model built from the data predicted that water quality impacts were restricted to the CO2 plume.
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Monitoring CO2 Injection within a Produced Gas Field: Initial Feasibility Studies for Angel CCS
More LessAuthors J. Deeks, R. Nesbit and K. HitchenSummaryMonitoring CO2 injection into the Angel depleted gas field is an important enabler of the Angel CCS project. Conventional seismic monitoring can be challenged within reservoirs containing depleted gas, so a suite of technologies is assessed for suitability to monitor the CO2. 1D rock physics modelling indicates that seismic monitoring within brine saturated parts of the reservoir may be effective, but monitoring CO2 saturation within parts of the reservoir containing residual gas saturation is more complex. Preliminary timelapse gravity modelling of the CO2 plume over time indicates that gravitational field changes are likely to exceed detectability thresholds within five years of injection, flagging this technology as a possible technology for monitoring plume movement within the residual gas column. Timelapse CSEM modelling shows that this technology would not be able to detect the planned CO2 injection volume due to the reservoir depth below mudline and the resistive underburden. Timelapse seismic and gravity are assessed as technologies worth continuing to evaluate for monitoring the CO2 plume in the Angel CCS project.
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Comprehensive Risk based Workflow to Develop Detailed MMV Plan for CO2 Sequestration Projects
More LessAuthors F. GuiSummaryA Measurement, Monitoring and Verification (MMV) plan is a requirement for subsurface CO2 sequestration projects. A complete MMV plan considers the reservoir location, depth, type, target disposal volume, and time requirement. It also considers the site characteristics, integrity of the storage complex, wells, and specific geologic features. Finally, it conforms to the local governing compliance regulations, guidelines, and mandates on MMV planning.
The MMV design process works within the risk management framework and starts after site selection by evaluating site-specific storage risks before proceeding to implement additional safeguards supported by monitoring in a stepwise approach. The full MMV plan development process evolves from the conceptual stage, through a feasibility stage, to a define stage and includes operations during pre-injection, injection, and site closure.
The risk-based plan is comprehensive to anticipate any unwanted CO2 migration and adaptive to change or expand monitoring as the CO2 storage is underway. The result is an explicit monitoring plan that demonstrates the achievement of objectives, supports strategic planning and field development, helps decision makers make informed choices, prioritize actions, and distinguish among alternative courses of action. The plan accounts for uncertainty, the nature of the uncertainty, and how it can be addressed.
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De-risking Fluid Injection Across the “F10 Fault” System using 2D and 3D Seismic, Harvey, Western Australia
More LessAuthors T. BellSummaryThe Harvey study site, located in the Southern Perth Basin, forms a part of the CSIRO’s research hub into testing new technologies and methods for carbon-capture storage. Prior to drilling new injection and observation wells with downhole fiber optic technology at Harvey, reprocessing and interpretation of 2014 acquired Cookernup 3D seismic survey was carried out to improve subsurface characterisation of the “F10 Fault” and surrounding damage zone. This subsurface site characterization study was deemed necessary to derisking the planned fluid injection well locations and, to better understand the fault architecture for improved simulation modelling of fluid migration across the large Permian-Jurassic aged rift fault structures.
Pre-Stack Depth Migration (PSDM) reprocessing was successful in enhancing the imaging of the F10 fault structures, capturing additional complexity in the fault geometry such as relay-ramps, and showed new faults in the top 500m that were not previously identified. These insights improved the positioning of the planned injection/observations wells and will allow for better simulation modelling of cross-fault flow during injection experiments.
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Techno-Economic Analysis of CCUS Hub Scenarios in Western Australia
More LessAuthors K. Michael, M. Loughrey, E. Williams, R. Sander, I. Havercroft, A. Hortle, C. Consoli, E. Pinto, N. Raji, M. Ironside and A. ZapantisSummaryWestern Australia provides ideal conditions for establishing carbon capture, utilization and storage (CCUS) hubs due to the co-location of abundant, highly suitable geological storage resources in saline aquifers and depleted fields with clusters of industrial emissions sources. Emitters include sources with high CO2 concentrations from gas processing, ammonia and fertilizer production that form a low-cost opportunity for the initial stages of a CCUS hub.
For techno-economic analysis, two main emissions clusters were identified: a) the Perth-Kwinana industrial area in the southwest of Western Australia with approximately 20 Mtpa of CO2 emissions and b) the Pilbara area in the northwest with approximately 30 Mtpa of CO2 emissions. Emissions in the Perth-Kwinana area are associated largely with power generation and alumina processing, whereas LNG processing, fertilisers and iron ore processing are the main CO2 sources in the Pilbara region. Approximately 5 Mtpa are reservoir CO2 separated from natural gas processing and high-CO2 streams from ammonia/fertiliser production and present a low-cost opportunity for the initial stages of a CCUS hub. The remaining 45 Mt of these emissions are associated with higher capture costs. Geological storage of CO2 is proposed in the offshore North Carnarvon Basin, which is a mature petroleum province.
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