Assessment Of CO2 Storage Potential Research Articles

Integrated Three-Dimensional Structural and Petrophysical Modeling for Assessment of CO2 Storage Potential in Gas Reservoir

Abstract Carbon dioxide (CO2) storage in oil and gas reservoirs is one of the most effective methods for enhancing hydrocarbon recovery efficiency and mitigating climate change by securely storing CO2. However, building a realistic three-dimensional (3D) geological model for these storage reservoirs poses a significant challenge. To address this, employing a novel methodology combining 3D structural and petrophysical modeling, our study presents a pioneering effort to assess the CO2 storage potential of the faulted reservoir between the G- and E-sands of the Lower Goru Formation in the Kadanwari Gas Field (KGF), Middle Indus Basin (MIB), Pakistan. Analysis of seismic data revealed a complex reservoirs structure affected by normal faults oriented in a northwest–southeast direction. These faults partition the reservoir into several compartments and could serve as potential pathways for CO2 migration. Three-dimensional structural modeling unveiled complex features, for example horsts, grabens, and half-grabens, formed through multiple deformation stages. Petrophysical modeling indicated promising reservoir characteristics, that is high porosity and permeability in the desired zone. Three-dimensional property models were generated using sequential Gaussian simulation to represent the distribution of petrophysical properties, for example porosity, permeability, shale volume, and water saturation. Geological uncertainties were incorporated enabling the calculation of pore volume distribution and corresponding uncertainty. A novel technique was developed to assess the probable CO2 storage potential in the KGF, considering its distinctive features. The study revealed a storage potential ranging from 10.13 million tons (P10) to 101.54 million tons (P90), with an average potential of 53.58 million tons (P50). Our study offers a comprehensive approach to evaluating CO2 storage potential in complex geological zones, filling a knowledge gap in existing literature on carbon neutrality efforts in Pakistan. These findings lay the groundwork for future initiatives in geological CO2 storage in the MIB and support the country’s efforts to reduce carbon emissions.

From abandoned mines to carbon sinks: Assessing the CO2 storage capacity of Austrian low-rank coal deposits

This study represents the first assessment of CO2 storage potential in Austrian coal seams. Coal samples were taken from Fohnsdorf and Leoben abandoned coal mines, with particular emphasis on the Fohnsdorf coal since Leoben coal reserves were largely mined during previous coal production. Several methods were used to compare coal characteristics, including Rock-Eval pyrolysis (RE), organic petrography, and low-pressure N2 and CO2 sorption measurements. Both Fohnsdorf and Leoben coal samples show low sulfur and ash yields, as well as correspondingly high total organic carbon (TOC) contents. The pyrolysis Tmax and vitrinite reflectance values agree with a low coal rank for both sites. According to the N2 adsorption measurements at 77 K, low-lying mire coals from Fohnsdorf show a higher BET-specific surface area (BET-SSA) and BJH pore volume compared to raised-mire coals from Leoben. However, sapropelic shales and high-ash coals from Leoben show the highest BET-SSA and BJH pore volumes of all investigated samples and considerably exceed the N2 adsorption volumes of pure coals from both locations (N2 uptake up to 16 cm3/g; avg. for all samples 5.4 cm3/g). In contrast, the mean adsorbed CO2 uptake measured at 273 K and ∼ 1 bar followed the order of Fohnsdorf low-lying mire coals > Leoben raised-mire coals > Leoben sapropelic coals and shales, ranging at ∼0.8 mmol/g, ∼0.7 mmol/g, and ∼ 0.2 mmol/g, respectively. This shows that BET-SSA and BJH equations did not allow for adequate estimation of CO2 adsorption capacity trends in the investigated sample set. Furthermore, based on the existence of a hysteresis loop between CO2 adsorption and desorption branches for all investigated samples, the occurrence of weak chemisorption phenomena during CO2 adsorption is indicated. This effect helps to increase CO2 uptake and storage safety since the chemisorption process is not fully reversible upon pressure decrease. Ultimately, the theoretical CO2 sequestration potential of the remaining unmined Fohnsdorf coal reserves was estimated at 4.65 million tons, with an additional potential for enhanced coal bed methane production due to the gas-rich nature of Fohnsdorf coals with an estimated 1.2 billion m3 of CH4 in place.

Assessment of CO2 storage potential in high water-cut fractured volcanic gas reservoirs—Case study of China’s SN gas field

CO2 storage is an important technique for achieving both carbon peak and carbon neutralization, and depleted gas reservoirs are primary potential candidates for geological CO2 storage. After 15 years of development, the recovery rate of the SN gas field in China has reached 70 % and entered the middle and late stages. Most importantly, it has entered the stage of high water cut, rendering the stabilization of production challenging. As the gas produced in this gas reservoir contains a considerable amount of CO2, high water-bearing wells can be selected for CO2 storage in volcanic depleted gas reservoirs on site. Therefore, in this study, combined with the salinity characteristics of the formation water of the target block, a buried-potential evaluation study on typical wells in volcanic gas reservoirs is conducted, the gas–water distribution characteristics of the gas reservoir after CO2 injection are evaluated, and the CO2 injection timing and volume are optimized. The results show that the different ion content in the formation water leads to two reaction processes: dissolution and precipitation of reservoir minerals. When the CO2 in the formation water is low, the reservoir is dominated by dissolution reaction and the CO2 mineralization buried amount is negative; gradually decreasing with the age of the reservoir. As more CO2 is injected into the formation, a considerable amount of HCO3– is produced. In this context, the formation water is dominated by a precipitation reaction, and the CO2 mineralization buried amount is positive. In 2026, compared with the dissolved buried capacity of 1.0 × 105 m3/d, the injection rate of 2.5 × 105 m3/d will increase by 6.38 × 108 mol. When the injection rate is 1.5 × 105 m3/d, the mineralization buried capacity is the highest (2.02 × 105 mol.). Combining the total amount of CO2 dissolution and mineralization storage, the total amount of storage is the highest (1.38 × 108mol.) when the injection rate is 2.5 × 105 m3/d, indicating that the SN volcanic gas reservoir has significant CO2-storage potential. Guided by the research results of this study, typical wells have been selected to inject CO2 for storage purposes.

Quantitative Evaluation of CO2 Storage Potential in the Offshore Atlantic Lower Cretaceous Strata, Southeastern United States

The geological storage of CO2 in the Earth’s subsurface has the potential to significantly offset greenhouse gas emissions for safe, economical, and acceptable public use. Due to legal advantages and vast resource capacity, offshore CO2 storage provides an attractive alternative to onshore options. Although offshore Lower Cretaceous reservoirs have a vast expected storage capacity, there is a limited quantitative assessment of the offshore storage resource in the southeastern United States. This work is part of the Southeast Offshore Storage Resource Assessment (SOSRA) project, which presents a high-quality potential geological repository for CO2 in the Mid- and South Atlantic Planning Areas. This is the first comprehensive investigation and quantitative assessment of CO2 storage potential for the Lower Cretaceous section of the outer continental shelf that includes the Southeast Georgia Embayment and most of the Blake Plateau. An interpretation of 200,000 km of legacy industrial 2D seismic reflection profiles and geophysical well logs (i.e., TRANSCO 1005-1-1, COST GE-1, and EXXON 564-1) were utilized to create structure and thickness maps for the potential reservoirs and seals. We identified and assessed three target reservoirs isolated by seals based on their effective porosity values. The CO2 storage capacity of these reservoirs was theoretically calculated using the DOE-NETL equation for saline formations. The prospective storage resources are estimated between 450 and 4700 Mt of CO2, with an offshore geological efficiency factor of dolomite between 2% and 3.6% at the formation scale.

Assessment of Co2 Storage Potential in High Water-Cut Fractured Volcanic Gas Reservoirs——Case Study of China Sn Gas Field

Assessment of Co2 Storage Potential in High Water-Cut Fractured Volcanic Gas Reservoirs——Case Study of China Sn Gas Field

SCENARIOS FOR THE DEPLOYMENT OF CARBON CAPTURE AND STORAGE IN THE POWER SECTOR IN A PORTFOLIO OF MITIGATION OPTIONS

Using the MIT Economic Projection and Policy Analysis (EPPA) model, we explore factors influencing carbon capture and storage (CCS) deployment in power generation and its role in mitigating carbon emissions. We find that in the 2∘C scenario with EPPA’s base-case technology cost and performance assumptions, CCS plays an important role in the second half of the century: by 2100 CCS is applied to almost 40% of world electricity production, with a third coming from coal with CCS and the other two-thirds from gas with CCS. Results on CCS deployment depend on the assumed fraction of carbon captured in CCS power plants, as emissions constraints get tighter and the carbon price rises. Adding options for higher capture fractions or offsetting uncaptured emissions leads to greater deployment of CCS than in the 2∘C base case. We provide a sensitivity analysis by making favorable assumptions for CCS, nuclear and renewables. We also explore regional differences in the deployment of CCS. We find that US and Europe mostly rely on gas CCS, whereas China relies on coal CCS and India pursues both options. We also assess how these projections align with assessment of CO2 storage potential, and find that storage potential is larger than storage demand at both global and regional scales. Ultimately, we find that under stringent mitigation scenarios, the power sector relies on a mix of technological options, and the conditions that favor a particular mix of technologies differ by region.

Assessment of CO2 Storage Potential in Naturally Fractured Reservoirs With Dual‐Porosity Models

AbstractNaturally Fractured Reservoirs (NFR's) have received little attention as potential CO2 storage sites. Two main facts deter from storage projects in fractured reservoirs: (1) CO2 tends to be nonwetting in target formations and capillary forces will keep CO2 in the fractures, which typically have low pore volume; and (2) the high conductivity of the fractures may lead to increased spatial spreading of the CO2 plume. Numerical simulations are a powerful tool to understand the physics behind brine‐CO2 flow in NFR's. Dual‐porosity models are typically used to simulate multiphase flow in fractured formations. However, existing dual‐porosity models are based on crude approximations of the matrix‐fracture fluid transfer processes and often fail to capture the dynamics of fluid exchange accurately. Therefore, more accurate transfer functions are needed in order to evaluate the CO2 transfer to the matrix. This work presents an assessment of CO2 storage potential in NFR's using dual‐porosity models. We investigate the impact of a system of fractures on storage in a saline aquifer, by analyzing the time scales of brine drainage by CO2 in the matrix blocks and the maximum CO2 that can be stored in the rock matrix. A new model to estimate drainage time scales is developed and used in a transfer function for dual‐porosity simulations. We then analyze how injection rates should be limited in order to avoid early spill of CO2 (lost control of the plume) on a conceptual anticline model. Numerical simulations on the anticline show that naturally fractured reservoirs may be used to store CO2.

Assessment of CO2 storage potential and carbon capture, utilization and storage prospect in China

Carbon capture, utilization and storage (CCUS) is regarded as a very promising technology to reduce CO2 emission in China, which could improve the contradiction between economic development and environment protection. In order to study the CO2 storage potential for deploying CCUS projects in China, considering China's special geological features and current national conditions, a new evaluation method of CO2 storage capacity was proposed using the mass balance approach combined with various CO2 storage mechanisms in different formations, and the CO2 storage capacity was calculated in saline aquifer for CO2-EWR, oil reservoir for CO2-EOR and coal bed for CO2-ECBM respectively. The result shows that China has great CO2 storage potential, which is estimated to be over 1841 Gt. The different features and application prospect of CO2-EWR, CO2-EOR and CO2-ECBM in China were analyzed, which give guidance on critical technologies breakthrough and costs reduction along the CCUS chain. With the joint effort and support by policy and finance, CCUS will make great contribution to the development of low carbon economy for China and the world.

World Bank CCS Program Activities in Botswana – Results and Lessons Learned

The World Bank Carbon Capture and Storage Trust Fund (CCS TF) was established in 2009 to support CO2 capture and storage (CCS) capacity and knowledge building in developing countries11The WB CCS TF donors include the governments of the United Kingdom and Norway, and the Global Carbon Capture and Storage Institute. CCS TF Phase 1 support for CCS in Botswana included an allocation of USD 1.4 million and had the objective of supporting the Government of Botswana in the following areas:1.Identifying potential geological reservoirs that can be utilized to store CO2 captured from coal-fired power plants;2.Evaluating institutional and regulatory arrangements for CCS deployment in the country and recommendations for reinforcing institutional capacity; and3.Providing training, education and capacity building at all stages throughout implementation, including a Study Tour for key individuals.For all three studies, the WB selected Environmental Resources Management Southern Africa (Pty) Ltd (ERM) as the lead consultant, in association with Wellfield Geosciences (Botswana) and Carbon Counts Company (UK) Ltd.The completed geological assessment found that there may be technical potential for geological storage of CO2 in Botswana's geological formations within the Kalahari Karoo Basin, including three areas of interest -- the Passarge Basin, the Lephephe Graben and the Mmashoro Low. There is, however, a general lack of CO2 storage-relevant geological data that needs to be developed, if a more accurate assessment of CO2 storage potential is to be undertaken. The Passarge Basin was seen to be worthiest of additional investigation, which could be done through the re-examination of existing data or through new geological exploration. The Mashoro Low and Lephephe Graben are in close proximity to the centres of current coal-bed methane (CBM) exploration, suggesting that the integration of CBM exploitation and CO2 storage processes could be considered.The regulatory and institutional assessment reviewed how CO2 storage could be implemented under the existing legislation and regulation, and identified the gaps, not covered within the existing framework. The assessment found that existing regulatory acts provide certain coverage for most of key elements of the CO2 storage life-cycle, including: storage site prospecting; storage site development licensing/permitting; regulatory oversight; and, provisions for mid- to long-term liability where a holder of the waste management license incurs a 30-year liability period. However, some clarification is needed to ensure this is the case. Also, the establishment dedicated government body, mandated to lead the development of CCS would benefit the ongoing CCS program in Botswana.If the Government of Botswana intends to pursue the development of the institutional and technical capacity for development and deployment of CCS technology in Botswana, the following activities should be considered:•Building CCS awareness and strengthening coordination across government and industry;•Establishment of a CCS technical implementation plan, including the preparation of a CCS roadmap; and•Carrying out additional analysis of existing geological data relating to one or more of the formations identified.Based on the experience gained from the execution of this study, the next phase of CCS development in Botswana, as well as similar activities elsewhere would benefit from:•Increased government and stakeholder involvement in all stages of the study;•A formally mandated government partner to support the undertaking of the study and to implement and take forward the findings; and•External technical input/review from experts with experience in the development and execution of CO2 storage projects. This could take the form of a project specific technical advisory panel or a technical panel we a broader mandate across all the CCS TF's activities.

CO2 enhanced oil recovery and storage using a gravity-enhanced process

CO2 flooding offers a means to recover significant amounts of oil while simultaneously sequestering CO2. Recent methods for CO2 geological storage have focused on CO2 injection into deep brine aquifers, or by water-alternating-gas (WAG) injection in a miscible gas flooding process using vertical wells. There is significant uncertainty in the amount of CO2 that can be stored using these methods owing to reservoir heterogeneity and variations in reservoir/fluid parameters. It would be useful therefore to have a more robust process that can also increase both CO2 storage and oil recovery in a symbiotic relationship, where increased storage leads to greater oil recovery.This paper considers an alternative process that maximizes both storage and oil recovery simultaneously using only horizontal wells in a gravity-enhanced miscible process. A reduced-order model (ROM) is developed to consider a wide range of reservoir heterogeneities and fluid properties. Monte-Carlo simulations using the ROM show that achieving very high storage and oil recovery is possible using the gravity-enhanced process and that the approach is very robust. For example, after 2.0 moveable pore volumes injected (MPVI), probabilistic forecasts show that CO2 storage efficiency across two standard deviations ranges from about 81% to 93%, indicating that nearly all of the available pore space (excluding immobile water) at the end of injection is occupied by CO2. Oil recoveries after 2.0 MPVI varied from 79% to 93% of the original mass of oil-in-place (OOIP). These storage and recovery efficiencies are significantly greater than any process reported to date. Response functions developed can also be used to estimate the maximum amount of stored CO2 and corresponding oil recoveries for a wide range of reservoir and fluid properties. Such estimates are critical for regional and national assessment of CO2 storage potential.

Preliminary Assessment of CO2 Storage Potential in the Rovuma Sedimentary Basin, Mozambique

Abstract Vast natural gas discoveries have been reported in recent years in the offshore sector of the Rovuma sedimentary basin, Mozambique. Subsequently the Mozambique Government approved a natural gas development plan contemplating, amongst other scenarios, the construction of natural gas processing plants in the Municipalities of Palma and Pemba. The work presented in this article is a preliminary assessment of the CO2 storage potential in the onshore Rovuma Basin, which for that purpose was subdivided into four sectors. Only the Palma - Mocimboa da Praia and Macomia - North Pemba sectors are conditions suitable for safe CO2 storage. In the Palma - Mocimboa da Praia sector, situated in the NE part of the Rovuma basin, where the potential reservoirs are the Alto Jingone/Quissanga Formation and the Mikindani Formation, the prospective storage capacity is estimated to range from 150 Mt to 300 Mt. In the Macomia - North Pemba sector, the reservoir consists of the lower units of the Pemba Formation, dating from the Upper Jurassic/Lower Cretaceous, with an estimated storage capacity varying from 85 Mt to 170 Mt. Mozambique seems to present an interesting case in favour of developing CCS projects under in the Clean Development Mechanism. This article aims to raise awareness between national authorities and research institutions about the relevance of initiating a detailed assessment of the CO2 storage in Mozambique, namely in the Rovuma basin.

Investigation of CO2 storage potential of the Durban basin in South Africa

Abstract The mitigation of anthropogenic carbon dioxide (CO2) emissions through technologies such as Carbon Capture and Storage (CCS) has been internationally identified as one of the major technical approaches that can be used to combat global climate change in fossil fuel dominated countries. The South African Centre of Carbon Capture and Storage (SACCCS) was established in 2009 to investigate the potential for CCS in the country. Results from a country-scale assessment of CO2 storage potential suggest that South Africa has a theoretical storage capacity of ∼150 Gt, of which 98% occurs offshore in Mesozoic sedimentary basins preserved on the submerged continental shelf. This paper will discuss the progress associated with the ongoing investigation of CO2 storage potential in the 10 000 km2, offshore Durban basin on the east coast of South Africa. With the use of existing data and information the geological development and CO2 storage suitability of the offshore Durban basin is assessed. The basin is structurally complex, hosting a number of horst and graben structures but is dominated by the Tugela Cone, a Tertiary-age, deep-water fan complex that is located seaward of the continental shelf. Although not formally given formation status, sequence stratigraphic correlation can be applied to the Jurassic to Cretaceous succession, separating it into four formations based upon onshore sequences in the Zululand basin to the north. Formations are namely; Syn-Rift, Makatini, Mzinene, St Lucia. Cenozoic sediments range in thickness from ∼1300 m to ∼2000 m comprising a variety of lithologies that cap the sequence. Re-analysis of existing legacy 2D seismic and exploration borehole data has been undertaken in the context of CCS to assess the CO2 prospectivity, geological evolution, and depositional architecture of this portion of the South African continental shelf.

High frequency enhancement of sparker sub bottom profiles with multichannel reflection processing

The Petrel Sub-basin Marine Survey was undertaken in May 2012 by Geoscience Australia and the Australian Institute of Marine Science to support assessment of CO2 storage potential in the Bonaparte ...

Assessment of CO2 storage potential in turkey, modeling and a prefeasibility study for injection into an oil field

Abstract The large amount of CO 2 that can be mitigated by geologic storage had gained interest during the last 15 years. Acceptance of CCS under CDM is still under discussion(IEA, 2008) however there are several pilot or field scale projects and monitoring surveys that are underway which will make the technology better known and resolve the risks involved. This study involves assessment of possible geologic sites for CO 2 storage and calculation of CO 2 emissions from thermal power plants with capacities >500 MWe, cement factories, steel industry, sugar factories and refineries in Turkey. In emission calculations IPCC methodology is used. Coupling of sources and sinks resulted in a decision to use the emissions from a cement factory which is about 130 km from the selected oil field, Caylarbasi. The cement factory does not have capture facilities yet, but during modelling it was assumed that CO 2 is available at the factory site. According to the results of the model study, during the project life of 20 years, enhanced oil recovery effect of CO 2 lasts 8 years and 2 million barrels of oil will be produced and the remaining 12 years are modelled as CO 2 storage phase which shows 220 million Sm 3 of CO 2 can be stored.The transportation phase was designed with two alternatives, pipeline transport and transport by tankers. Economic evaluation at 100$/barrel of oil value, it will be possible to produce for 6 years. For the following years during CO 2 storage, incentives are necessary to cover operating costs so that project will continue for 20 years. Since the initial investment is already made, only the operational costs must be financed. Natural CO 2 field in Dodan is another possibility for geologic storage, the field has already produced 7 billion Sm 3 of CO 2 for the BatiRaman EOR project. Total capacity is about 10 billion Sm 3 . Other possible storage sites are deep saline aquifers, which were encountered in Thrace region, Central Anatolia and South Eastern Turkey and salt caverns of the soda mines. The experience of the Turkish oil industry for use of CO 2 in EOR application in BatiRaman field will be utilized if and when such an application is required.