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EAGE GeoTech 2022 Sixth EAGE Workshop on CO2 Geological Storage
- Conference date: April 4-6, 2022
- Location: London, United Kingdom
- Published: 04 April 2022
20 results
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Cost-Effective Seismic Surveying for CO2 Storage: Learnings from Smeaheia/Øygarden Survey Planning.
Authors R. Martinez, K. Duffaut, P. Ringrose, A. Santi, S. David and T. TrudengSummaryIn order to support offshore developments in carbon capture and storage, a novel, low-cost Ocean Bottom Node (OBN) seismic survey have been designed. The survey is to be acquired over a proposed test site across the Øygarden Fault in the Horda platform region offshore Norway. The aim is to improve the imaging of the fault and the resolution of the juxtaposed sedimentary units required to re-evaluate the risk of storing CO2 over a segment of the Beta Structural high. All, while using a limited set of 50 nodes. Evaluation of the acquisition configuration showed that receiver arrays allowing for high-resolution imaging and advance velocity inversion have divergent technical specifications. Meeting both objectives, while crucial for addressing de-risking and CO2 storage monitoring challenges, is not straightforward at low cost. Targeted imaging using hybrid OBN configurations may represent a cost-effective alternative to resolve this challenge, while sparse OBN acquisition, for velocity inversion and re-migration of legacy data, may comprise a low-cost solution for de-risking CO2 storage over uncertain or highly complex structures.
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Caprock Characterization of the Northern Lights CO2 Storage Project, Offshore Norway
Authors N.H. Mondol, L. Grande, T.I. Bjørnarå and N. ThompsonSummaryThis study investigates the caprock quality of Early Jurassic Drake Formation shales drilled in 17 wells in four oil and gas exploration blocks in the Aurora CO2 storage site, the northern North Sea using the Young’s modulus-Poisson’s ratio rock physics template. The template computes theoretical values of dynamic elastic properties of common constituents (e.g., clay, quartz, calcite, and organic matter) and helps characterize caprock behaviors (brittle versus ductile). Results show that the Drake Formation shales in the Aurora area have a wide range of Young’s modulus and Poisson’s ratio values and behave predominantly ductile to less ductile. Brittleness is a complex function of rock strength, lithology, texture, and control caprock shear failure and fracture potential. The brittleness behavior of Drake Formation shales deviates significantly compared to the classification proposed by Perez and Marfurt (2014) . Also, two other elastic property-based brittleness indices suggested by Fawad and Mondol (2021) and Grieser and Bray (2007) differ. The studied wells have a wide range of structural depth, explaining the diagenetic variation, hence variable brittleness indices. The discrepancies among the brittleness indices warrant the need for basin-specific or even formation-specific templates if the formation differences are significant.
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Numerical Modeling on CO2-EOR and its Storage Potential: a Case Study of Iranian Off-Shore Oil Field
Authors M. Babashah and F. FereydoonianSummaryDue to the many environmental issues caused by countless usage of carbon fuels, public efforts are trying to find sustainable solutions for the problems we are facing nowadays. One of the practical solutions examined during the last decades is CO2-EOR technology, which can be simultaneously implemented as a storage project for the anthropogenic CO2 gas.
This study investigates implementing CO2-EOR technology in an off-shore oil field located in Iran by using numerical simulation. ECLIPSE simulator is used for the modeling purpose to investigate the factors affecting the CO2-EOR process in order to identify the optimum conditions to recover the maximum amount of oil in actual conditions and determine the injectivity constrain in the reservoir.
The factors of vertical and horizontal permeability, fluid viscosity, saturation endpoints as well as temperature and pressure of injection, the combination of CO2-N2, and the combination of CO2-C1 are examined in this study in detail.
According to the results, the permeability, fluid gravity, the temperature and pressure of injection, as well as the type of flooding fluid have the most influential parameters on production respectively. However, the number and location of injection wells also affect the dynamic simulation results.
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Methodology of Site Screening and Selection for the Purpose of Geological Storage of Carbon Dioxide
SummaryThis paper discusses the site screening and pre-selection process adopted for the first geological storage of carbon dioxide in Russia—focusing on the methodology. Main objective of CCS projects is reducing or offsetting greenhouse gas (GHG) emissions by polluting industries and assessing options for the disposal of carbon dioxide (CO2) as a by-product in the areas of operation.
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DAS Deployed at Seabed for CO2 Storage Monitoring
Authors V. Bremaud, E. Rebel, E. Zamboni and C. SagarySummaryThe work presented in this paper is a first step to assess the capabilities of fiber optic cables deployed at seabed to acquire and process 4D seismic data to monitor future CO2 storages. A data set acquired with a Permanent Reservoir Monitoring (PRM) system installed at seabed has been analyzed. Four-component (4C) optical sensors are interconnected by optic fiber cable along a 2D line and active seismic shots located above this optical cable have been simultaneously recorded by the 4C sensors and by DAS along the optical cable connecting these 4C sensors. This data set is ideal to compare the sensitivity of DAS versus the one of conventional sensors. The first step was to understand what is physically recorded by these optical cables. Then, a PP processing sequence has been applied to the PZ summation (combination of hydrophone and vertical component of accelerometer), the radial component of accelerometer and the DAS. The results obtained are very encouraging and are clearly placing fiber optic cables horizontally deployed at seabed as part of the next generation of CO2 storage monitoring toolbox.
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Quantification of Injected CO2 Volumes from 4D Seismic Anomalies & Associated Uncertainties
Authors T. Berridge, E. Rebel, T. Blanchard, D. Rappin and C. Le MagoarouSummaryTo facilitate large scale deployment of Carbon Capture and Storage (CCS) a reliable monitoring strategy must be in place to verify that the injected CO2 remains well contained and is not leaking from the storage reservoir. Monitoring using time-lapse (4D) active seismic benefits from a large amount of know-how from the oil and gas industry and is one of the most accurate methods to determine the spatio-temporal evolution of the plume. Here we present a workflow developed to quantify the volume of CO2 directly from 4D seismic anomalies by forward simulating the expected seismic response using a petro-elastic model. The method has been applied to successfully model case study data from the Otway pilot project and has been able to quantify the mass of injected CO2 from the observed 4D anomalies.
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MMV Long Term Strategies to Calibrate and Support CO2 Storage Flow Models Using Focused Seismic
Authors H. Al Khatib, E. Morgan and V. BrunSummaryTo “substantially reduce global greenhouse gas emissions to limit the global temperature increase in this century to 2 degrees Celsius while pursuing efforts to limit the increase even further to 1.5 degrees” as stated in the Paris Agreement ( UN, 2015 ), most greenhouse gas control scenario include massive CO2 geological storage also called CCS. According to the IEA, from over 40 Mtpa CO2 in 2021, CCS yearly capacity needs to increase to 1.6 Gtpa CO2 in 2030 ( IEA, 2021 ). To make it happen, subsurface industry will have to overcome (amongst other) the following two critical challenges: social acceptance and Monitoring, Measurement and Verification (MMV) as technically and economically viable for long term monitoring (50–100 years) ( Lumley, 2021 ).
In this abstract, pros & cons of frequent full field 4D seismic monitoring strategy are presented, and a supplement/alternative approach is introduced ( Morgan et al., 2020 ) that capitalize on the key features of CCS to calibrate flow models where and when needed with an agile focused seismic measurement.
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Monitoring and Appraisal of CCUS Projects: Remote Sensing Using 3D and 4D Seismic Data
Authors R. Williams and C. HanSummarySubsurface sequestration of CO2 is seen by many as an essential route towards carbon Net Zero. The process contains several geological challenges, which we may now be able to better answer with improved technology and subsurface understanding. This presentation will look at addressing structural uncertainty, aquifer/reservoir analysis and CO2 injection monitoring using state of the art AI derived technology through a series of case studies. Structural analysis is undertaken using AI fault detection networks which can prove vital for trap, seal, and migration studies, whilst it can have a major significance on the planning and safe delivery of injection wells. Aquifer understanding on a previously untapped structure may contain several risk factors. Using frequency decomposition and RGB blending it is possible to forward model both the seismic reflectivity and colour blend to reduce risk and identify plausible geological scenarios. After a successful CCUS appraisal, a method of monitoring the injected CO2 is required that is both consistent and reliable. AI derived geobodies enables an interpreter to consistently extract a CO2 infill plume across multiple vintages of data, ensuring the structure is filled as planned and history matching the volume of injected fluids against the volume of stored fluids.
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Basin-Scale CO2 Storage Site Screening – an Example from the Northern North Sea Basin
Authors M. Booth, R. Porjesz, S. Otto, G. Duval, P. Park, A. Khalid, C. Olivares, S. Calvert and A. SatterleySummaryA multi-criteria basin-scale screening methodology is presented with the aim to rank possible CO2 storage sites for future detailed analyses and potential CO2 injection permitting applications. The methodology presented here focuses on a basin-scale assessment of the geological formations in the UK and Norwegian North Sea area focusing on the geology, the injectivity of the reservoirs and the geochemical and geomechanical properties. This screening process developed by CGG is called the Storage Play Quality Index (SPQI) and it combines geology, stratigraphy, petrophysics, reservoir engineering, geochemistry, geomechanics and data science to assess the storage quality of selected geological formations in the Northern North Sea area for the permanent storage of CO2. The regional-scale SPQI can be applied to any geographic region, both offshore and onshore, with sufficient input data.
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Supporting Renewables by Making HD Seismic Simple and Affordable
Authors A. Ourabah, D. Lawton and A. ChatenaySummaryGeothermal and CCUS are technologies used for many decades to support and complement the energy industry and are considered today essential technologies to realistically achieve a net zero carbon future. A good knowledge of the subsurface is an important requirement for both of these industries to make sure the subsurface conditions are right and also to monitor the field through its life. However, having access to the latest seismic acquisition and processing technologies at an affordable price is a real challenge for these green industries which don’t have the budget nor the resources to run a complex seismic program and derive all the attributes needed for them. In this paper we will discuss how the latest seismic technologies can make seismic more affordable and accessible to these industries using the example of a CCUS UHD seismic acquisition run in 2021.
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Attenuation Measurement for Monitoring Injected CO2 at Cami Field Research Station, Alberta, Canada
More LessSummaryFor seismic monitoring injected CO2 during geologic CO2 sequestration, it is useful to measure seismic attenuation. Seismic attenuation directly connects to different petrophysical parameters of reservoir rock or CO2 capture and storage site. We have used an approach for measuring attenuation by iteratively identifying a sparse set of the strongest reflections in the seismic trace and stacking their waveforms. This method is straightforward and requires no sophisticated inverse algorithm. It is data-driven and applied to the DAS VSP dataset from the CaMI Field Research Station (FRS) in Newell County, Alberta, Canada. High-quality attenuation-quantity cross-sections are obtained. Strong attenuation within the CO2 injection zone around the CO2 injection well is observed, which is interpreted as being related to the injected CO2 at the FRS.
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Simulators for the Gigaton Storage Challenge. A Benchmark Study on the Regional Smeaheia Model.
Authors T.H. Sandve, A.B. Rustad, A. Thune, B. Nazarian, S. Gasda and A.F. RasmussenSummaryInitial benchmarking of the OPM Flow simulator with the CO2STORE option and the Eclipse E300 compositional simulator on the Smeaheia regional model concludes that both simulators handle the needed complexity in the model and show good scalability up to 16 MPI processes on an Equinor workstation, but the OPM Flow simulator is significantly faster than E300 for this case. The OPM Flow simulator was also run on the Simula eX3 cluster and there it shows good scaling up-to 512 MPI processes, which means it can simulate the multi-million model in less than an hour. The E300 simulator uses the Peng-Robinson EOS model for CO2 and tabulated values for the brine properties assuming constant temperature while OPM Flow use Span-Wagner for CO2 and computes the properties directly and thus considers the initial temperature gradient in the model. The slight differences in the results between the simulators can be traced back to the different PVT models used by the simulators.
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Hybrid Structural Petrophysical Joint Inversion as a Novel Inversion Technique for CO2 Monitoring
Authors M. Jordan, D. Rippe, R. Anouar, P. Eliasson and C. Schmidt-HattenbergerSummaryWe present a novel hybrid structural-petrophysical joint inversion approach for monitoring of geological storage of CO2 both onshore and offshore. It integrates multiple geophysical datasets to produce consistent geophysical models that can serve a key input for a reliable quantification of reservoir parameters, e.g., saturation or pressure. The structural encourages structural similarity of the different geophysical models, while in the petrophysical joint inversion, models are linked using quasi-linear petrophysical models that can be defined from well logs. As the petrophysical joint inversion will only produce meaningful results where the petrophysical models are valid, part of the joint inversion workflow consists of exploring their validity in the model space. An important part of the efficient application of the method is a suitable workflow, which we demonstrat using seismic and electrical data from 2012 repeat surveys at the Ketzin CO2 storage pilot in Germany.
The hybrid structural-petrophysical joint inversion results show clear improvements over independent inversions and structural and petrophysical joint inversions. Hybrid joint inversion combines the benefits of both approaches, suggesting hybrid joint inversion as a tool that can support quantitative interpretation of reservoir parameters and the amount of injected CO2.
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New Concepts for Independent and Transparent Monitoring of CO2 Storage Verification
Authors V. Oye, B. Goertz-Allmann, N. Langet, A.M. Dichiarante and D. KuehnSummaryWe are presenting a new concept for CO2 storage monitoring that is based on independent and transparent monitoring. To existing, state-of-the-art automatic monitoring methods, a second layer of decision support system is required such that informed decisions can be taken from operators and regulators in near-real time. To prepare for these decision support systems, the relevant parameters need to be extracted from often complex monitoring data. In the ENSURE ACT3 project, we will work on these aspects.
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Carbon Management Canada CaMI Field Research Station: Advancing Monitoring Technologies for CCS
Authors M. Macquet, B. Kolkman-Quinn and D. LawtonSummaryThe Containment and Monitoring Institute (CaMI) of CMC, in collaboration with the University of Calgary, operates a comprehensive CO2 injection and storage program at its Field Research Station (FRS) in Newell County, Southern Alberta, Canada. We are injecting a small amount of CO2 (48.4 tonnes at the end of 2021) at shallow depth (300m) to simulate a leakage from a deep CO2 storage reservoir. The controlled amount of injected CO2 is used to test and develop monitoring technologies, and to estimate CO2 detection threshold for the different tools. We will give a brief overview of the broad range of geophysical and geochemical monitoring technologies tested at the site, including distributed acoustic sensing (DAS), continuous seismic monitoring (broadband stations, surface and borehole geophones), and active seismic surveys. We will focus on the results of vertical seismic profile (VSP) time-lapse monitoring and electrical resistivity tomography (ERT) semi-continuous monitoring. We will demonstrate their detection thresholds (few tonnes for the ERT, few 10’s of tonnes for the VSP) and how they can be used as an early warning tool to detect loss of containment of deep large scale CO2 storage sites.
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Svelvik CO2 Field Lab - Update on Site Behaviour and Fluid Migration During CO2 Injection
Authors M. Jordan, P. Eliasson, A. Grimstad and G. De JagerSummaryThe Svelvik CO2 Field Lab was designed for the development and testing of methods for quantifying saturation and pressure, in particular for CO2 monitoring applications. We present an update on the knowledge about the migration and distribution of the injected CO2 in the subsurface at the Svelvik CO2 Field Lab to facilitate planning for future experiments at the test site. Based on observations of site behaviour during water and CO2 injection and the corresponding effects on the seismic data, we develop an understanding of the migration of the CO2 from the injection point at 65 m depth, both in space and time. The purpose of this presentation is to provide potential users of the site an understanding of which scenarios can be observed at the Svelvik CO2 Field Lab (e.g., CO2 plume, migration of small amounts of CO2, leakage around wells, and potentially CO2 dissolution), and how to plan acquisition of the desired data.
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Impact of Impurities and it’s Concentration on CO2 Injectivities
More LessSummaryAs part of an ongoing Carbon dioxide capture and storage research, the aims and objective of this Abstract study is to look into the thermodynamic details behaviour of Carbon dioxide in the present of variable set of gaseous impurities before, during and after injection into a geological subsurface storage system including depleted oil and gas reservoir formation using industry standard numerical methods.
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Geologic CO2 Storage Optimization Under Geomechanical Constraints
Authors N. Khoshnevis Gargar, E.G.D. Barros, D. Loeve, S.P. Szklarz and O. LeeuwenburghSummaryIn this study, an ensemble-based optimization framework has been applied to optimize CO2 injection strategies in a case study representative of storage in depleted gas reservoirs. An optimization problem was formulated for a realistic synthetic case study aimed at investigating the potential value of optimization in the context of CO2 storage. Time-varying yearly CO2 injection rates of multiple injection wells were optimized to maximize the net present value (NPV) of the CO2 storage activities while honoring geomechanical constraints associated with fault stability based on the shear capacity utilization indicator.
The results of multiple optimization experiments show that when the constraints are imposed the CO2 injection allocation is more balanced across the injectors and over time. This leads to slightly lower NPV for almost the same amount of CO2 injected in optimized case, but it allows us to identify safe injection strategies that still achieve the storage objectives. These results confirm the potential of numerical optimization as a tool to assist CO2 storage practitioners to design safe injection plans.
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Assessment of a Neogene CCS Prospect Using 3D Seismic Analysis, Norwegian North Sea
More LessSummaryCarbon capture and storage has been a necessity for reducing the global carbon emissions to net zero by 2050. Assessment of geological carbon storage fields is playing a key role in projections on action scenarios. North Sea is one of the most promising areas for CCS with its large prolific saline aquifers reaching the storage capacities of megatons and vast database of exploration and production database. The aim of this study is describing a potential gas and carbon storage field situated to the Northeast of Zulu Øst field on the Patch Bank Ridge in the Norwegian North Sea using seismic facies analysis. The seal and reservoir units in the northern lobe are identified and compared with Zulu Øst Field in terms of seismic facies and thickness. Depth of the northern lobe’s crest is deeper than 800 m. below sea level, which is on the limit for safe subsurface storage of supercritical CO2. Therefore, it can be a good option for CCS development when it is compared with the Zulu Øst field’s crest depth (770 m). Skade formation sands are also suitable reservoirs for both lobes with their depths and thicknesses.
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The Impact of Background Water Flow on CO2 Plume Migration in a Tilted Aquifer
Authors M. Awag, E. Mackay and S. GhanbariSummaryCO2 injection into deep saline aquifers for storage is considered as a promising tool for reducing CO2 emissions. To estimate the storage capacity and assess risks associated with CO2 leakage, an accurate understanding of the post-injection migration, spreading and trapping of the mobile plume of CO2 is crucial. We performed a numerical modelling analysis on the migration of an injected CO2 plume into a dipping aquifer subjected to background water flow, and incorporating residual and dissolution trapping of CO2. We described the plume post-injection migration at different periods, the early and late post-injection periods. Our study focuses on the impact of the background water velocity on the early post-injection migration of the plume. We estimate the height, migration distance and velocity of the plume, and the amount of mobile CO2 within the plume to identify how fast and far it migrates. Our results reveal that as the background velocity increases, the plume migrates further up-dip; however, its height decreases with time. This suggests that the mobile CO2 volume decreases in the aquifer for greater background flow velocities, reducing the risk of leakage. Also, the plume decelerates during its vertical migration and accelerates with background flow velocity during its lateral migration.
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