International Journal of Greenhouse Gas Control最新文献

This work presents a detailed supercritical CO₂ storage resource estimation for the stacked basalt reservoirs in the Grande Ronde Basalt of the Columbia River Basalt Group in eastern Washington and Oregon. The assessment aims to derisk the commercialization potential of geologic carbon storage in basalt by leveraging both structural and mineralization trapping of CO₂ in basalt. The structural closures formed by anticlinal ridges and synclinal valleys in Yakima Fold Belt are excellent physical traps to accommodate injected supercritical CO₂. Rigorous hydraulic testing, well logs and simulation results from the Wallula Basalt Pilot #1 well showed the occurrence of 17 suitable permeable injection zones (up to 2,496 mD) intercalated with dense seals (∼2.6E-10 mD) in the Grand Ronde Basalt. In addition, geochemical studies showed fast reactions between supercritical CO₂ and dissolved basalt minerals to form stable carbonates. Our calculation indicates up to 40 gigatons (P90) of mineralization storage resources exist in the Grande Ronde Basalt reservoirs.

A workflow that considers regulatory and technical constraints applicable to subsurface CO₂ injection projects was developed to determine fluid injection rates accurately. The constraints considered include, but are not limited to, maximum injection bottomhole pressure, maximum injection pressure at the surface or wellhead pressure, and threshold vibration velocity. The workflow was developed and tested using a reservoir model developed from site characterization data of an Illinois Basin CarbonSAFE Phase II notional storage project. The Nexus® reservoir simulation software suite and the Peng-Robinson equation-of-state were used to perform compositional dynamic simulations. Reservoir modeling results indicated that (1) the regulated and technically feasible CO₂ injection rate of a vertical well is predetermined by the most stringent parameter amongst maximum bottomhole pressure, maximum wellhead (surface injection) pressure, and threshold vibration velocity constraints; (2) the threshold vibrational velocity constraint predetermines CO₂ injection rate for high-permeability injection zones; and (3) the most stringent constraint for low-permeability injection zones could be either the maximum bottomhole pressure or the maximum wellhead pressure. However, the injection rate may be further reduced if faults or hydraulically conductive fractures are present within the injection zone and adjacent formations because the pressure required to reactivate the faults may be lower than maximum injection bottomhole pressure, maximum wellhead pressure, and vibrational velocity constraints.

The aim of the work was to identify the basic structural properties of basalts from the Central European Volcanic Province in Poland in the context of assessing the possibility of permanent CO₂ storage. The research was carried out on rock samples from three Polish basalt mines. An experiment on the reactivity of minerals contained in basalt was carried out in the original geochemical reactor. In an isolated system with a capacity of 100 cm³, proper analyzes of mineral carbonation were carried out for 65 days at a temperature of 293 K and a pressure of 0.43 MP. The pressure, pH and temperature of the process were recorded. The mechanism of structural changes that occurred in pores of different diameters was determined. SEM microscopic analyzes showed a transformation of the macroporosity and morphology of the sample. The formation of new voids and transport channels was observed, which resulted from the partial dissolution and conversion of minerals. At the same time, the pore surface area in the transitional pores and finest micropores has been reduced, indicating that the surface area of these pores have been overbuilt and the tight intrapore transport pathways have been clogged. The gravimetric measurements of the sorption capacity of basalt in relation to gaseous CO₂ were also conducted. After the mineral carbonation process, the efficiency of CO₂ accumulation decreased, which confirmed that the previously free pore space had been filled. Comprehensive scanning, structural and sorption studies confirmed the migration and multi-track transformation of minerals from basalt.

The deployment of CO₂ capture technologies presents opportunities to store fossil fuel emissions from industries and power generation (CCS) and to enable carbon utilization (CCU). However, the costs for early CCS projects are high, and this is a challenge in terms of their economic viability, requiring a strong climate policy with high carbon prices for implementation. This work details a techno-economic assessment of the cost of carbon capture based on a hybrid method and individual project approach, using first-of-a-kind contingency factors and learning rates to study the evolution of carbon capture costs as installed capacity increases over time. The work is based on a case study of 147 Swedish industrial and combined heat and power plants (total of 176 stacks). The results are presented as marginal abatement cost curves, with consideration of early mover CCS projects and learning rates. Deployment scenarios are also presented that take into account an expected increase in the CO₂ price. The findings indicate that when accounting for first-of-a-kind contingencies (100 % and 200 % increases in Nth-of-a-kind costs), 90 and 17 projects, respectively, of the total 176 emission sources studied have specific CO₂ costs of <300 €/t. However, high learning rates (12 %) can reduce the capture costs from first-of-a-kind to Nth-of-a-kind levels within some 30 project installations (100 % contingency). With lower learning rates (3 %), the first-of-a-kind costs are reduced by 10 %–20 %. With the expected increase in CO₂ prices, a peak in carbon capture deployment is observed around Year 2035, at a carbon price of 200 €/t.

This study assesses the potential of in-situ injection of CO₂ dissolved in water for carbon mineralization in serpentinite, specifically in British Columbia (B.C.), Canada. This method has been proven in basaltic rocks in Iceland using the Carbfix technology. These and other techniques for CO₂ storage are needed to help limit the effects of climate change alongside other mitigation and adaptation strategies.

Feasible areas in B.C. are assessed via nine different multi-criteria index overlay analyses for logistical factors such as access to water, proximity to sources of CO₂ and electricity infrastructure. The relative feasibility scores, on a scale of 0 to 10, are overlain on the 84 viable ultramafic formations. Then, geological data was evaluated to prioritize which sites contain 1 km² mapped voluminous serpentinite. Three sites in southern B.C. show the highest potential for a CO₂ storage project: 1) Shulaps complex, 2) Coquihalla serpentine belt, and 3) Tulameen intrusion. The Shulaps and Coquihalla are mantle massifs, and Tulameen is an Alaskan-type ultramafic intrusion. All sites contain partially to pervasively serpentinized harzburgite or dunite. Additionally, six different carbon storage potential estimates are shown for these three potential sites, for Shulaps 141.2–18,682 MtCO₂, for Coquihalla 9.4–1245 MtCO₂, and for Tulameen 2.8–373.6 MtCO₂. In future work, these sites will be further evaluated for feasibility for a pilot test CO₂ injection.

In Denmark, Geological Carbon Storage (GCS) has been prioritized as an immediate solution for climate action. The Havnsø domal structure has been identified as one of the most promising locations for GCS because its size and properties are believed to be suitable for GCS. However, the preliminary assessments, based mainly on old, sparse, and low-quality seismic data, are uncertain regarding the prospective storage resource and the integrity of the structure. To enable informed decisions and planning of the storage operations and as part of a large-scale acquisition campaign targeting several similar onshore structures throughout Denmark, a seismic data acquisition work was conducted in 2022 in the area. The purpose of the survey was to delineate the structural closure and map possible geologic features, such as faults, that could jeopardize GCS operations. In total, 132 km of high-fold and high-resolution 2D profiles were acquired using an innovative dual-element recording system for both deep and shallow subsurface imaging purposes. The recording comprises two vibrating sources and a combination of nodal recorders spaced at 10 m, and 2-m-spaced microelectromechanical systems (MEMS)-based recorders attached to a moving landstreamer. The seismic data contain information on all horizons of interest for GCS. The structure is estimated as a well-defined four-way closure, where the reservoir is continuous. A thick, mostly uniform sealing rock is interpreted and no large-scale faults are found in the near surface. The results, supported from existing background information, provide crucial information to assist further decisions and actions related to future storage operations in Havnsø.

Carbon mineralisation in underground mafic and ultramafic formations, known as in-situ carbon mineralisation, has emerged as an attractive technology for permanent CO₂ storage. Despite its potential, this method has received limited attention compared to conventional CO₂ storage in sedimentary formations. However, increasing interest from countries and companies in utilising this approach to permanently store CO₂ via carbon mineralisation has grown in recent years as part of the wider carbon capture and storage expansion seen globally.

This review paper aims to provide an in-depth overview of in-situ carbon mineralisation technology. The paper covers key factors crucial for successful implementation, including water consumption, CO₂ injection rate, risk of CO₂ leakage, injectivity, fracture characterisation, pressure management and induced seismicity, thermal effects, surface area of minerals, groundwater contamination, injection strategy, monitoring of confinement, and reservoir modelling. The paper also discusses pilot tests and projects, highlighting their outcomes. Furthermore, it discusses the costs associated with in-situ carbon mineralisation and provides a case study.

The primary objective of this paper is to increase awareness and understanding of this relatively new technology within the carbon capture and storage industry. By shedding light on the benefits and challenges of carbon mineralisation in mafic and ultramafic formations, this review aims to encourage further research, development, and adoption of this promising approach for CO₂ emissions reduction and permanent CO₂ storage.

Carbon dioxide capture and storage (CCS) is considered an option for energy-intensive industry to reduce its greenhouse gas emissions. Although it is well known that CCS faces technological, economic and societal challenges, how these challenges interact in a real-life industry has not yet been investigated collectively in a place-specific context. This study fills that gap by looking at the dynamic interactions between technological, economic and societal aspects, with the aim of clarifying enablers for and barriers to the implementation of industrial CCS in the North Sea Port industrial cluster, and identifying a course of action. The analysis was based on literature, interviews and group model building. By using group model building, expert stakeholders were brought together from industry, government and environmental non-governmental organizations. The participants built a qualitative model of the system dynamics of the implementation of industrial CCS in the North Sea Port industrial cluster jointly and on the spot. Enablers and barriers, such as costs, government's decisiveness and public support, are strongly interrelated. Public support plays a key role in multiple feedback loops in the system of industrial CCS implementation. The interdependence of societal and techno-economical elements needs to be acknowledged and responded to. There is need for transparent public engagement to build public support for CCS, and decisiveness and commitment from industry and government to transform that public support into successful and responsible CCS implementation.

The chemical absorption method using amine-based aqueous solutions as absorbents is considered a critical technology in the mitigation of CO₂ emissions. However, the trade-off between absorption performance and energy consumption presents a significant challenge for large-scale industrial applications. In this study, we propose using N-(2-hydroxyethyl)ethylenediamine (AEEA), 1-(2-amino Ethyl)piperazine (AEP) and piperazine (PZ) to regulate the CO₂ capture characteristics of 1-(2-hydroxyethyl)piperidine (HEP) aqueous solution. We found that the addition of promoter AEEA/AEP/PZ increases the CO₂ absorption and desorption performance of HEP aqueous solution. We established the CO₂ capture mechanism, which involves the generation of HEPH⁺, carbamate, and bicarbonate during the absorption of CO₂. During the desorption process, the bicarbonate can be decomposed, while the carbamate remains in the solution. Furthermore, we obtained data on the kinetics and corrosion characteristics of the blended absorbents. The absorption resistance of the three blended amine aqueous solutions is concentrated on the gas film, accounting for approximately 77 %. The corrosion rate of blended amine-enriched solutions on 20# carbon steel decreases with the increasing mass fraction of promoters or CO₂ loading. SEM-EDS analysis revealed the presence of a dense FeCO₃ oxide film on the surface of 20# carbon steel, which protects the carbon steel sheet from further corrosion. Overall, the proposed absorbents indicated a promising potential in the CO₂ capture applications.

In light of the application of CO₂ micro-nanobubbles (MNBs) in distributed carbon dioxide capture and storage (CCS), a series of experiments were conducted to investigate the stability of CO₂ MNBs. Prior to the in-situ assessments, foundational laboratory experiments were performed to evaluate the stability of the MNBs. Subsequently, a small-scale in-situ CO₂ MNB injection test was conducted to measure the CO₂ MNB density in the extraction well.

The bubble density was measured using a resonance mass spectrometer, which effectively discerns bubbles from solid particles. Furthermore, the behavior of the injected CO₂ MNB water was monitored through electric resistivity surveys. The findings revealed that CO₂ MNBs and O₂ MNBs exhibit low ζ-potentials at low pH values. Regarding bubble density, the CO₂ MNB remained relatively stable at a pH of 4, proximate to the point of supersaturation. As time elapsed following injection, the bubble density in the extraction wells of the in-situ CO₂ MNB water injection experiments steadily increased, implying the replacement of groundwater in the aquifer by injected CO₂ MNB. The resistivity survey effectively delineated the migration area of the CO₂ MNB water, indicating that CO₂ MNBs could persist in the aquifer even up to one day post-injection. Laboratory measurements of ζ-potential and bubble density further corroborate the complete displacement of water in the aquifer by CO₂ MNB water, leading to a reduction in porewater pH and ultimately facilitating the stable retention of CO₂ MNBs.