World CCUS Conference 2025
- Conference date: September 1-4, 2025
- Location: Bergen, Norway
- Published: 01 September 2025
1 - 20 of 110 results
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Cost Sensitivity Analysis for Geological CO2 Storage at SW Ontario
More LessAuthors M. Baghmolaei and R. LefebvreSummaryThis study explores the cost sensitivity of geological CO2 storage in Southwestern Ontario, an area identified for its potential to support Canada’s carbon reduction targets under the Net-Zero Emissions Accountability Act. Combining reservoir simulation results with a review of cost models, the analysis evaluates eight cost estimation frameworks. The models were optimized against a validation benchmark based on Smith et al. (2021) . Among them, McCollum & Ogden’s model (2006) demonstrated the highest predictive accuracy, as confirmed by regression and error analysis. Sensitivity analysis using Taguchi and ANOVA methods revealed that well depth has minimal cost impact within the studied area, while the number of wells has a moderate influence. Conversely, mass flow rate significantly affects total costs, with higher rates reducing expenses, underscoring its importance in optimizing cost-efficiency. These findings provide insights into the financial feasibility of CO2 storage in the region and highlight the need for tailored cost models to account for local geological and operational variations. This study serves as a foundational resource for decision-makers aiming to advance sustainable CCUS implementation in Southwestern Ontario.
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Earthquakes Triggered by Injection of Produced Water in North America: Implications for Large-Scale Storage of CO2
More LessAuthors M. ZobackSummaryLarge-scale injection of supercritical CO2 into saline aquifers is an analogous process to the disposal of large volumes of saltwater co-produced with oil and gas (SWD). Large-scale SWD in saline aquifers over the past 15 years in the mid-continent of North America has caused a remarkable increase of intraplate seismicity. Since 2010, approximately 3.5 billion m3 of produced water has been injected into sedimentary layers that are in hydraulic communication with seismogenic geologic basement in Oklahoma and Texas alone, triggering more than 4,000 M ≥ 3.0 earthquakes. If large-scale CO2 storage projects are associated with induced seismicity, they could be perceived by the public as a hazardous activity which should not be allowed to continue. Earthquake sequences in crystalline basement are frequently triggered by very small pressure increases in overlaying injection zones, frequently about 1 MPa. Injection into sedimentary formations in hydrologic communication with faults in underlying seismogenic basement is responsible for all relatively large (M≥4) induced earthquakes associated with SWD to date and CO2 injection into such formations must be avoided.
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Catalyst-Induced Carbon Dioxide Conversion and Utilization during In-Situ Heating of Oil Shale: Immeasurable Potential
More LessSummaryThe hydrogenation of CO2 into renewable fuels is a particularly promising utilization pathway, in which thermocatalytic CO2 hydrogenation is regarded as the most viable and scalable technology. In-situ shale conversion operates at temperatures between 300 and 500 °C, which aligns closely with the reaction conditions required for thermocatalytic CO2 hydrogenation to methanol. This similarity suggests that integrating thermocatalytic CO2 hydrogenation into in-situ shale conversion could reduce CO2 emissions while enhancing the economic value of shale oil production. Therefore, by leveraging both CO2 hydrogenation with H₂ and CO2 reduction with H2S, in-situ shale conversion has the potential not only to mitigate self-generated CO2, H2, and H2S but also to address CO2-included waste gases from human activities on the surface. In this study, we successfully demonstrate the thermocatalytic hydrogenation and reduction of CO2 during in-situ shale conversion by heating simulations. This work shows extremely large carbon capture and utilization (CCU) potential, with initial projections of 15 m3 of CO2 conversion and utilization per tonne of shale oil produced. Further estimates indicate that the recoverable resources of this in-situ conversion shale oil in the Ordos Basin (China) alone exceed 70 billion tons, corresponding to a potential CCU of ∼1,050 billion cubic meters.
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Machine Learning-Informed Reservoir Simulation for Performance Mapping of CO2-EOR and Storage in the SACROC Field
More LessSummaryThis study presents an innovative approach to integrating machine learning (ML) with reservoir simulation to enhance the predictive accuracy and efficiency of CO2-enhanced oil recovery (CO2-EOR) and storage in the SACROC field of the Permian Basin. Traditional reservoir simulation methods are computationally expensive and time-consuming, particularly when dealing with complex geological formations. By leveraging ML algorithms—Random Forest, Gradient Boosting, and XGBoost—this study aims to provide faster and more accurate predictions of oil and CO2 saturation distributions. A dataset of 13,600 data points, including key reservoir parameters such as permeability and porosity, is used to train the models. Performance evaluation through statistical metrics such as RMSE, MAE, and R2 identifies Random Forest as the most effective model, achieving the lowest prediction error and highest accuracy. The results demonstrate the capability of ML models to accurately map reservoir dynamics over short- and long-term periods, offering valuable insights for optimizing CO2 injection strategies and improving carbon capture, utilization, and storage (CCUS) efficiency. The findings highlight the potential of ML-driven frameworks to support decision-making processes in subsurface engineering, ultimately contributing to sustainable energy development and climate change mitigation efforts.
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UccUS Energy: An Innovative Approach to Underground-Carbon-Capture, Utilization, and Long-Duration Energy Storage for Trilemma of CCUS
More LessAuthors J. WangSummaryThe global economy’s reliance on fossil fuels has led to resource depletion and high CO2 emissions, exacerbating the energy trilemma of security, affordability, and sustainability. Traditional carbon capture, utilization, and storage (CCUS) methods face challenges due to low CO2 concentrations in industrial waste gases, complex processes, and high energy consumption. This study proposes an innovative solution: Underground-carbon-capture, Utilization, and Storage (UccUS) combined with Long-Duration Energy Storage by Differential Pressure Power Generation (LDES-DPPG), termed “UccUS Energy”. Utilizing high-temperature, high-pressure, and high-salinity underground saline water layers as natural CO2 absorbents and energy storage containers, this approach eliminates the need for expensive ground facilities. Industrial waste gas or air is injected into saline layers, capturing CO2 underground while compressing residual nitrogen for energy storage. Results demonstrate high security through large-capacity underground storage, affordability with 90% cost savings in carbon capture and additional power generation income, and strong sustainability by enabling low-cost carbon reduction and reliable long-duration storage for intermittent renewable energy. Successfully applied in multiple Chinese oil and gas fields, UccUS Energy offers a scalable solution for global energy transition, leveraging widespread saline water resources to achieve net-zero goals while addressing the energy trilemma. This approach represents a transformative pathway for sustainable development.
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On Backflow in a CO2 Injection Well During Transient Operations
More LessAuthors Z. YangSummaryThis paper utilizes the OLGA code, an enhanced commercial flow assurance tool for CO2 applications, to evaluate the potential backflow of CO2 injection wells under different storage conditions. The OLGA simulation accurately predicts the thermal dynamics of the CO2 stream in the Snøhvit CO2 injection well during its shut-in period. The simulation results show that there is no backflow from the reservoir into the CO2 injection well during normal operational conditions, such as the shut-in of the wellhead choke, if the CO2 entering the well has the same temperature as the ambient temperature, regardless of whether the CO2 is single-phase or two-phase flow in the well prior to or during the shut-in period. However, backflow into the well may occur when the CO2 temperature at the wellhead is higher than the ambient temperature. If the flow assurance tool is coupled with a reservoir simulator, the amount of backflow volume and fluid composition can be accurately predicted. Backflow is not expected to be an issue during continuous CO2 injection into the well, but it may occur if the pipeline and well system experience large-scale unstable flow, such as slugging.
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Guidance on Subsea Barrier and Isolation Philosophy for Carbon Capture and Storage (CCS) Systems
More LessSummaryIOGP’s Subsea Committee kicked off a new work stream specifically focused on subsea CCS. The primary objective of their work has been to create a new IOGP guidance document for subsea CCS developments. With numerous subsea CCS projects advancing globally, IOGP set an ambitious goal to release the first of the guides by early 2024 – IOGP Report 665 - Design guidance for subsea carbon capture and storage systems. This has been followed up with an addendum IOGP Report 665-1- Subsea Barrier and Isolation Philosophy for CCS Systems that covers barrier and isolation philosophy for CCS systems.
The presentation will start by outlining the objectives behind the new guidance. It will then delve into the structure and content of the document in more detail. Additionally, the audience will be offered several potential ‘use cases’ for the subsea CCS guidance document. It will also discuss the methods adopted highlighting the collaborative efforts of the team of Operators and Suppliers, the challenges they faced, and the innovative design and development solutions adopted.
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The Impact of Small-Scale Heterogeneities on Residual Trapping: Case Study from the Otway CO2 Storage Site
More LessAuthors C. Spurin, C. Callas, D. Bason, M. Allison and S. BensonSummaryThis research investigates how small-scale heterogeneities in rock formations affect CO2 storage in subsurface reservoirs, focusing on core samples from Australia’s Otway CO2 storage site. The study was motivated by observations of unexpected rapid CO2 plume migration at storage projects like Sleipner, which were not predicted by prior modelling efforts.
Using medical CT scanning, we imaged steady-state CO2 injection in cores taken from the Otway site. A key finding was that porosity distribution alone couldn’t predict CO2 distribution patterns, as some influential features were smaller than the medical CT scanner’s 0.6mm resolution.
The study identified various types of heterogeneities within a 5m interval of the Otway basin, including fine layers, thick layers, and more complex patterns. These different heterogeneities resulted in diverse CO2 distribution and trapping patterns. Importantly, these variations occurred at scales smaller than typical reservoir model grid sizes. The findings contribute to Special Core Analysis (SCAL) for modeling a 10,000-ton CO2 injection project in the Otway basin, highlighting the importance of incorporating small-scale heterogeneities in reservoir models for accurate prediction of CO2 behavior.
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Exploring Dissolved CO2 Storage Potential in Shallow Clastic Reservoirs of Rift Basins
More LessAuthors J. Ye, J. Almeida De Carvalho, P. Lu and W. WeiSummaryThis study explores the viability of dissolved CO2 storage in shallow clastic saline aquifers of rift basins, where conventional methods face challenges. Using advanced reactive transport modeling techniques, we investigated the impact of various parameters such as aquifer properties, water chemistry, and reservoir mineralogy on dissolved CO2 storage. The research reveals a rapid increase in CO2 solubility up to 2,000 feet depth, with slower variations thereafter due to salinity influences. It indicates shallow clastic saline aquifers have a potential to store ∼6 Mt of CO2 per km3 of rock. Furthermore, the study highlights the significant effects of brine salinity, reservoir mineralogy, and injection water composition on trapping mechanisms, with carbon mineralization being enhanced in high-salinity formation water scenarios. The results demonstrate the potential for safe and efficient CO2 storage through geochemical interactions in shallow clastic reservoirs. Factors such as aquifer salinity, mineralogy, dipping angles, and injection water chemistry play critical roles in determining storage success.
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Using Integrated Machine Learning Property Modeling for Delineating Optimum CO2 Storage Sites
More LessAuthors A. AhmadSummaryIn this challenging era of deciding Carbon Capture & Storage (CCS) sites, it becomes not only important but also critical to use all available data for drilling better wells for injecting carbon into the underground storage. This abstract would summarize a case study where seismic inversion & machine learning property modeling data was used to effectively delineate the tight vs non-tight sands; this resulted in a better development strategy for the injection of CO2 into the field. The integration of machine learning & seismic inversion results resulted in deciding the best area for injection of CO2 and planning the development phase for CO2 injection across the entire project life for underground storage.
The objective of this study was to effectively delineate the non-tight sands through seismic inversion & machine learning for underground CO2 storage, map these non-tight sand intervals throughout the field and recommend new well locations in the cretaceous deltaic depleted reservoir for CO2 storage.
It is also important to mention here that the machine learning application for property modeling helped in creating 1000’s of scenarios with blind testing validation.
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A Framework for Holistic, Transdisciplinary, Multi-Criteria Optimization of the Monitoring System for Geological CO2 Storage
More LessAuthors Y. Heggelund, M. Lien and D. OttoSummaryAn optimized monitoring system for geological CO2 storage must be built on knowledge from multiple disciplines and the involvement of multiple stakeholders. In this work we demonstrate a transdisciplinary approach to secure the technical, operational, economic, and societal embeddedness of the solutions for monitoring geological storage of CO2. The Analytical Hierarchy Process (AHP) framework was chosen since it enables group discussions for selecting the relevant criteria, it enables assessment of the monitoring solutions by multiple experts, and not least is a transparent and structured framework for decision making. A synthetic brine-filled storage site representative of the Norwegian Continental Shelf was defined as a test site for the study, and a set of three realistic monitoring alternatives was defined by experts, considering the risks and features of the site. The study was also informed by the Societal Embeddedness Level (SEL) which is a novel methodology designed to assess the societal requirements necessary for the successful deployment of technological innovations, particularly those impacting the environment.
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Seismic Monitoring of CO2 Migration through the Shallow Fault: Otway Project Case Study
More LessAuthors K. Tertyshnikov, N. Beloborodov, R. Isaenkov, B. Gurevich, O. Collet, P. Shashkin, M. Vorobev, A. Almukhametova and R. PevznerSummaryThe shallow CO2 controlled release experiment has been conducted at the Otway International Test Centre (OITC) in Victoria, Australia. The project carried out the injection of approximately 16 tonnes of gaseous CO2 at a depth of ∼77–87 m in the vicinity of the near-surface strike-slip sub-vertical Brumby’s Fault. The seismic monitoring technique – 4D reverse VSP (RVSP) – was employed to monitor the rapid development and movement of the carbon dioxide plume and obtain the 3D time-lapse distribution of the CO2 during and after the injection. The RVSP method involves installing a dense array of surface geophones around the injection well and includes using a high-frequency (∼ 1kHz) downhole source deployed in a nearby monitoring well. The RVSP approach allows the daily acquisition of a 3D seismic vintage, providing frequent updates on the plume evolution. We present the observation of the CO2 migration patterns using the results of seismic tomography of the RVSP time-lapse data. The seismic monitoring program highlights the effectiveness of the 4D reverse VSP technique for rapid data acquisition, making it well-suited for capturing fast-evolving subsurface processes.
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Baseline Monitoring of Surface Deformation and Seismicity in Kalundborg, the Planned CO2 Storge Site in Denmark
More LessAuthors Z. Zarifi, T. Dahl-Jensen, A. Jarna Ganerød, G.C. Sauvin, S. Torset and M. KeidingSummaryThe Havnsø structure in the Kalundborg CO2 storage site is a four-way anticline closure that has been evaluated as a suitable CO2 storage unit. As an input to baseline monitoring of surface deformation, we used the C-band satellite data from European Space Agency (ESA) for Interferometric Synthetic Aperture Radar (InSAR) analysis to detect surface deformation with millimeter-resolution. The data were processed using GMTSAR software. Although challenges with high levels of vegetation and small water lakes reduced the coherency of backscattered signals, but enough reliable result obtained to make our analysis possible. We Integrate InSAR results, with geomechanical model and feasibility studies for deployment of a local seismic network to tailor the planned baseline monitoring strategy in the Kalundborg CO2 storage site.
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Quantifying Long-Term CO2 Storage Containment via Sequential Multi-Physics Trapping Models
More LessAuthors P. Ringrose, A. Callioli Santi, T.K. Yun, M. Macut, C. Delbet and C.F. BergSummaryIn this review paper, we show how sequential multi-physics trapping processes operate within the storage complex to generally reduce the risks of re-migration and leakage. Using the Invasion Percolation Markov Chain model we show how the probability of these CO2 migration events within a multi-barrier geological system can be quantified.
Considering the possibility of vertical migration pathways, such as via active fracture zones or well-bore damage zones, we identify several geomechanical and geochemical processes which have a tendency to add other ‘multi-physics’ retention processes, especially geomechanical creep and carbonate precipitation. The role of these coupled geochemical and geomechanical processes is complex and an important topic of ongoing research. However, laboratory studies to date suggest that geomechanical creep and carbonate mineral precipitation tend to act slowly but effectively to reduce the risks of vertical migration of CO2 in the subsurface.
To gain better insights into CO2 fluxes along faults and fractures in the Earth’s crust, we are studying natural tectonic degassing in the North Atlantic region, where many natural CO2 fluxes have been quantified. We plan to use these natural analogues as a reference model for quantifying possible future episodic leakage fluxes from CO2 storage facilities.
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Development of Sealing Materials for CCUS Packers Resistant to Supercritical CO2 and Analysis of Corrosion Mechanisms
More LessSummaryThis paper aims to investigate the corrosion resistance of different sealing rubber materials in a supercritical CO2 environment. Ten base rubber materials commonly used in the oil and gas industry, including fluoro rubber, nitrile rubber, hydrogenated nitrile rubber, ethylene propylene diene monomer (EPDM) rubber, and perfluoro elastomer (FFKM), were studied. The materials’ mechanical properties and mass/volume change rates before and after corrosion were tested. Through comprehensive comparative analysis, the best-performing base rubber material was selected. Different vulcanization systems and reinforcing materials were compared and optimized. The final rubber composite material was subjected to gas permeability and gas burst resistance tests, achieving the rubber material’s gas diffusion coefficient-temperature curve and verifying its gas burst resistance. The corrosion mechanism of supercritical CO2 on rubber was analyzed through molecular structure characterization. Based on the final formulation, CCUS packer rubber was manufactured, and its sealing performance was tested under simulated CCUS downhole conditions. This research contributes to addressing the current shortcomings in the gas sealing performance of CO2 injection packers, offering significant economic and social benefits.
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Geophysical and Geochemical Methods for In-situ CO2 Mineral Storage Site Characterization and Monitoring
More LessAuthors J.S. Junker, A. Obermann, M. Brennwald, M. Voigt, H. Maurer, S. Wiemer and A. ZapponeSummaryIn a pilot project in Helguvik, Iceland, in-situ CO2 mineral storage is tested for the first time using saline water instead of fresh water for injection in the field scale. We present three geophysical and geochemical techniques that are novel to in-situ CO2 mineral storage site characterization and monitoring. The baseline characterization, employing single-hole electrical resistivity tomography (ERT) and crosshole seismic measurements, revealed decameter-thick basaltic layers and allowed us to interfer the subsurface porosity and permeability distributions. Rock physics modelling predicts significant seismic velocity increases associated with secondary mineral precipitation, suggesting crosshole seismic time-lapse surveys as a valuable monitoring tool. Results of the ERT timelapse measurements show distinct variations between the baseline and the timelapse measurements, indicating potential resistivity changes due to secondary mineral precipitation and fluid substitution. Geochemical monitoring of a Helium tracer confirms that injected water has reached the monitoring well at 100 m distance, whereas the CO2 concentration in the same well shows no significant increase relative to the pre-injection state. This work demonstrates the potential of combined geophysical and geochemical methods for characterizing and monitoring in-situ CO2 mineral storage, highlighting ERT and crosshole seismics as valuable tools.
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The Role of Pressure in Monitoring CO2 Injection in Depleted Gas Reservoirs
More LessAuthors J. De Kok, J. Hild, M. Bouts, G. Thürschmid and W. SchiferliSummaryThis paper gives an overview of which pressure data can be collected and how it can contribute to monitoring containment, storage resources and injectivity. Also, uncertainties and limitations related to the interpretation of the pressure data are discussed. The focus of this paper is depleted gas reservoirs, since the uncertainties in pressure monitoring are larger in depleted gas reservoirs than for CO2 injection in saline aquifers. Due to the complex reservoir behavior during CO2 injection into depletion gas reservoirs, the analysis of the pressure data often carries significant uncertainty. Therefore, only relatively large leaks can directly be distinguished using pressure monitoring. However, monitoring pressure has great value in operations to ensure safe operations, confirm well integrity and adjust operating strategy and storage resource estimates.
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Well Control for CO2 Wells, Risk for CO2 Blowout?
More LessAuthors S.I. ØdegårdSummaryCO2 -storage, similar to drilling for petroleum production, represents a risk in terms of accident potential related to “blow-out” during drilling and considerable loss of acceptance in society for the storage of CO2 in the underground.
Gradually, by establishing a multitude of wells for CO2 -storage, in-fill drilling in mature CO2 storage regions will be required. Accordingly, there will be occurrences with drilling of CO2 wells in the vicinity or within existing reservoir volumes containing CO2. Thus, new wells will be established near or penetrating in the CO2 conductive layers.
To address and bridge the knowledge gap between petroleum wells and CO2 wells, Equinor, Shell, Eni, Ebn, CNOOC, Transocean, Baker Hughes, Wild Well Control, Sintef, Gassnova and eDrilling have conducted a project, where drilling fluids mixed with CO2 under relevant pressure/temperature conditions are investigated in laboratory experiments/tests.
The knowledge from the laboratory experiments is synthesized into simulation software from eDrilling for safe and efficient planning of such operations. This software includes solubility of CO2 in oil and water-based drilling fluids, as well as the impact of phase transition from liquid to gas (“boiling”) when the mixture of drilling fluid and CO2 (liquid) is circulated to the surface.
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A High-Resolution Deep Learning Model for CO2 Injection at the Otway Field Validation Site
More LessAuthors C. Callas, M. Allison, D. Bason, I. Ju, G. Wen and S.M. BensonSummaryThe GeoCquest Field Validation (GFV) experiment aims to test and refine the approaches developed for predicting plume migration and trapping using high-resolution simulations. However, the multi-physics problem, highly nonlinear governing equations, necessity for high spatial and fine temporal resolution, and inherent uncertainty in the subsurface leads to computationally expensive numerical simulations that can take up to a week to run using conventional methods. Therefore, a U-FNO machine learning model was developed to maintain the complexity and high resolution of the simulations while providing a faster alternative that was then used to estimate breakthrough times at the monitoring well and characterize the uncertainty associated with the experiment. This model can also be used to examine reservoir characteristics, history match to PNL data and optimize injection strategies for trapping. The model created results in over 80,000x speed up in simulation time. Our model achieved a plume error of 3.2% for the training dataset and 6% for the test set. We used the model to understand the probability of CO2 reaching the monitoring well. We found that by day 23 of injection, there was over an 80% probability that CO2 would reach the monitoring well.
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Investigating CO2 with Light Impurities for CO2 Storage: Data and Model Comparison
More LessSummaryGeological CO2 storage is a key strategy in reducing greenhouse gas emissions, but its economic viability is challenged by risks associated with complex CO2 phase behaviour, especially when mixed with impurities present in capture processes, as well as those present in underground reservoirs. These impurities complicate aspects such as injection risks, storage capacity, and safety. The CO2plus project aims to address these challenges by developing models to analyse the intricate phase behaviour during injection and storage, focusing on issues like hydrate formation, Joule-Thomson cooling, and salt clogging.
In this contribution phase equilibrium data for CO2 + Ar, CO, H2, H2S, N2, O2, and SO2 are collected from literature and curated for further model development. The Soave-Redlich-Kwong, Peng-Robinson, Cubic Plus Association, and PC-SAFT equations of state are fitted to the curated data and the model descriptions are compared to those of the newly updated EOS-CG, a model designed specifically for humid gases and CO2-rich mixtures. Overall, the models do comparatively well, but EOS-CG outperforms all models in the mixture critical regions.
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