The Importance of CO2 Composition Specification in the CCUS Chain

Carbon Capture and Storage (CCS) is considered as one of the major industrial solutions to enable the energy transition. This technology permits to reduce footprint of current carbon intensive industries on the short and medium-term and can be a long-term solution for hard to abate carbon emission sectors. Even if CO2 transportation and storage has been deployed for a few decades, as in Enhanced Oil Recovery applications or for food/medical CO2 applications, CCS sets novel challenges as it implies the development of widespread transportation and storage hubs with multiple CO2 sources coming from different industries. CO2 specification becomes one of the major elements when establishing a CCS chain and necessitate cross discipline efforts covering among other: design requirements (process, flow assurance, thermodynamics), system integrity (corrosion), Health Safety and Environment (HSE), and reservoir, delineating the capture and conditioning facilities to be considered by the source plants. CO2 specification is highly impacted by the transportation mode: ship transportation requires a purity of about 99.5% CO2, while pipeline transportation can allow purity as low as 96% CO2. Moreover, some impurities, such as H2S, NOx, SOx, even at ppm levels, may trigger a set of corrosion mechanism with the risk of impairing the overall integrity of the system. Establishing a CO2 specification for a CCS chain is complex, requiring anticipating (i) the CO2 sources characteristics (ii) the chain characteristics and its operating conditions (iii) the potential impact of impurities in order to establish the best compromise between impurities maximum allowable concentration versus safe CCS chain with optimized design, operations and costs.

Carbon Capture and Storage (CCS) is considered as an important technology to reduce CO 2 emission from electrical power generation and other industrial processes. In the CCS chain, i.e. from capture to storage via transportation, it is essential to realize accurate measurement of CO 2 flows for the purpose of accounting and potential leakage detection. However, there are some significant challenges for the current flow metering technologies to achieve the specified 1.5% measurement uncertainty in the EU-ETS (European Union — Emissions Trading Scheme) for all expected flow conditions. Moreover, there are very few CO 2 flow test and calibration facilities that can recreate CCS conditions particularly two-phase CO 2 flow in pipelines together with accurate measurement standards. As one of the most potential flowmeters that may be used in the CCS chain, Coriolis flowmeters have the advantages of direct measurement of mass flow rate regardless of its state (liquid, gas, gas/liquid two-phase or supercritical) in addition to the measurement of temperature and density of CO 2 for the characterization of flow conditions. This paper assesses the performance of Coriolis flowmeters incorporating a soft-computing correction method for gas-liquid two-phase CO 2 flow measurement. The correction method includes a pre-trained backpropagation neural network. Experimental work was conducted on a purpose-built 25 mm bore two-phase CO 2 flow test rig for liquid mass flowrate between 300 kg/h and 3050 kg/h and gas mass flowrate from 0 to 330 kg/h under the fluid temperature of 19∼21 °C and pressure of 54∼58 bar. Experimental results suggest that the Coriolis flowmeters with the developed correction method are capable of providing the mass flow rate of gas-liquid CO 2 flow with errors mostly within ±2% and ±1.5% on horizontal and vertical pipelines, respectively.

Differences in the public perception of CCS in Germany depending on CO2 source, transport option and storage location

Today global warming is a serious threat to living things and the earth, according to WMO, 2019 is the second hottest year after 2016. The average temperature for the last 10 years has reached its highest point. CCS technology is a series of activities that start from capturing CO2 from sources of CO2 emissions, namely the industrial sector and electricity generation. After being captured, CO2 is transported through pipelines or ships to the CO2 storage location in the appropriate storage, it can be geolocical or ocean storage. Each CCS project will use the most suitable method to transport CO2 and pay attention to planning, health and safety regulations. These problems can be overcome by a method, a Superstructure method. A problem with CCS may occur when the source and sink locations are not necessarily in a single region, so it is possible that the CCS process can occur in a multi-region where the source and sink locations are far apart and with many regions. The development of multi-region studies was carried out in this research, namely with the boundaries of the regions of Kalimantan, Sulawesi and East Java with a total of 4 sources and 2 sinks. Development is carried out by making mass transfer scenarios using superstructure method and cost calculations based on Total Annual Cost (TAC) then optimized with optimization software to get the minimum cost. In this study, the optimum CCS network has been determined in Kalimantan, Sulawesi and East Java regions with specific TAC US$ 11,126,782.2/Mt.

In recent years, there has been a growing interest in the Gulf Region in Carbon Capture and Storage (CCS) as well as the use of Carbon Dioxide for Enhance Oil Recovery (CO2-EOR) in the Middle East Region. Unlike H2S, carbon dioxide does not support combustion. However, carbon dioxide can cause asphyxia if inhaled in large quantities. While many Middle Eastern oil producers have experience with sour oil and gas fields, there is little or no experience with CCS and CO2-EOR operation. For CCS and CO2-EOR projects, carbon dioxide is typically transported in pipelines at pressure above its critical pressure (73.82 bar). In the event of depressurization or loss of containment, the escaping CO2 will experience a sudden change in phase which may result in dry ice projectiles being expelled at very high velocities. Other hazards include cryogenic burns to the skin and catastrophic failure of carbon steel equipment due to low temperature metal embitterment. Dealing with CO2 presents oil producers with new safety challenges. This paper discusses the safety aspects of handling carbon dioxide in CCS and CO2-EOR projects.

Poster ESG7 Designing cost-effective methods for implementing measurement, monitoring and verification (MM&V) plans for subsea CO2 storage is an active area of research globally. Despite some preliminary research and examples overseas, there remains a lack of established protocols and configurations for offshore carbon capture and storage (CCS) monitoring overlying storage sites and an absence of methods to establish environmental impact in the event of leakage. Over the last 4 years, CSIRO in collaboration with ANLEC R&D and CarbonNet have been undertaking research in the Gippsland region to inform the development of assurance monitoring approaches for subsea CCS operations to address three key technical assurance monitoring challenges: The ‘signal-to-noise’ problem: distinguishing CO2 release signatures from similar naturally occurring variability to reduce false alarm rates in future baseline monitoring design; characterising impact: determining the level of CO2 release that would be associated with environmental impact at a range of scales; and attributing impact: distinguishing changes resulting from other drivers and pressures in multiple-use zones (e.g. climate change) from the activities of CCS operations. The research has included a wide variety of approaches and technologies including the development and testing of fixed and mobile autonomous monitoring systems, chemical and acoustic sensing and the collection of biological datasets. These data have been used in the development of biogeochemical models and to define possible integrated MM&V frameworks. This paper will summarise this research and identify how it could be applied for offshore CO2 storage projects around Australia. To access the poster click the link on the right. To read the full paper click here

The implementation of carbon capture and storage process (CCS) has been unsuccessful to date, mainly due to the technical issues and high costs associated with two main stages: (1) CO2 separation from flue gas and (2) CO2 injection in deep geological deposits, more than 300 m, where CO2 is in supercritical conditions. This study proposes, for the first time, an enhanced CCS process (e-CCS), in which the stage of CO2 separation is removed and the flue gas is injected directly in shallow reservoirs located at less than 300 m, where the adsorptive phenomena control CO2 storage. Nitrogen-rich carbon nanospheres were used as modifying agents of the reservoir porous texture to improve both the CO2 adsorption capacity and selectivity. For this purpose, sandstone was impregnated with a nanofluid and CO2 adsorption was evaluated at different pressures (atmospheric pressure and from 3 × 10−3 MPa to 3.0 MPa) and temperatures (0, 25, and 50 °C). As a main result, a mass fraction of only 20% of nanomaterials increased both the surface area and the molecular interactions, so that the increase of adsorption capacity at shallow reservoir conditions (50 °C and 3.0 MPa) was more than 677 times (from 0.00125 to 0.9 mmol g−1).

CO2 transport from capture sources to storage sites is one of the leading parts of the carbon capture, and storage (CCS) infrastructure that needs to be optimized in order to reduce the capital, operating and maintenance (O&M) costs. This paper conducts a systematic overview of CO2 transport and identifies the knowledge gaps with a view for application to optimal CCS Hub design. The findings show that much research has been focused on the engineering and economic consequences in pure CO2 streams while in most real field studies the captured CO2 is accompanied with trace impurities that can affect the "intelligent" cost model's confidence to estimate CO2 pipeline costs. The impacts of different topographical conditions in current models on the economic pressure drop and inlet pressure is another challenge that has received little attention in the literature. Most cost-effective pipeline systems described in the literature, are based on the simple point-to-point design while the capture of CO2 from multiple sources and transport to multiple distributed CCS injection wells is an issue for the industrial-scale rollout of CCS. The lack of sufficient studies on the flow variations within CO2 networks is the last discussion in this research review. Further, there have been several cost models reported in the literature, and most of them are based on the costs of the natural gas pipeline infrastructure. However, the higher operating pressure of CO2 and the various impurities in CO2 streams from capture plant may require construction material specifications that will affect cost models. A systematic understanding of how CO2 pipelines contribute to CCS chain economics is still lacking. While many optimization challenges have been solved for natural gas pipeline networks, there are different thermodynamic behaviors for CO2 that require further optimization. The potential minor impurities that could occur in CO2 pipelines such as water (H2O), nitrogen (N2), oxygen (O2), hydrogen sulfide (H2S) and methane (CH4) can add complexity compared to the transport of natural gas.

Carbon Capture and Storage (CCS) is a critical technology in the U.S. strategy to achieve net-zero emissions and combat climate change. This review explores the market challenges and policy recommendations associated with CCS deployment, emphasizing its role in decarbonizing hard-to-abate sectors such as power generation, manufacturing, and industrial processes. Despite significant advancements in CCS technology, widespread adoption faces barriers, including high capital and operational costs, insufficient market incentives, and public acceptance challenges. Moreover, the lack of comprehensive infrastructure, such as CO₂ transport pipelines and storage facilities, poses a significant hurdle to scaling CCS operations. Policy frameworks like the 45Q tax credit and state-level initiatives have spurred CCS projects, but inconsistencies in regulatory standards and insufficient federal and state collaboration hinder broader adoption. This review highlights the importance of integrating CCS into broader climate policies, leveraging public-private partnerships, and fostering innovation to reduce costs and enhance efficiency. Stakeholder engagement is crucial to addressing community concerns and ensuring equitable implementation, particularly in regions with high CCS potential. The analysis identifies key strategies to overcome these challenges, including enhancing financial incentives, streamlining permitting processes, and investing in infrastructure development. Additionally, it underscores the need for robust monitoring, reporting, and verification (MRV) frameworks to ensure the long-term safety and effectiveness of CO₂ storage sites. Case studies of successful projects in the U.S. and other countries are examined to extract best practices and inform future initiatives. By addressing market and policy barriers, CCS can become a cornerstone of the U.S. decarbonization strategy, contributing to economic growth, job creation, and environmental sustainability. This review provides actionable policy recommendations to accelerate CCS deployment, supporting the U.S. in meeting its climate goals and maintaining global leadership in clean energy innovation.

Carbon capture and storage (CCS) from oil facilities is an important and effective way to reduce the concentration of carbon dioxide in the atmosphere. Consequently, gas-processing facilities will be dealing with a tremendous quantity of CO2 with high pressure. Therefore, the aim of this study is to simulate the dispersal of CO2 gas leakage from high-pressure pipelines of the gas-processing facilities. The modeling of CO2 leakage from pipelines at CCS process has been problematic because of the lack of appropriate source term models that handle the complex behavior of CO2 correctly during release. In this study, OLGA 7 simulator was utilized for predicting outflow rates and duration of ruptured CO2 pipelines at different leakage scenarios (leakage sizes). OLGA 7 simulator was selected due to its capabilities in simulating gas pipeline leak scenarios in various designs and operating conditions such as Operation Pressure, Isolation valve spacing (IVS), and Emergency response time (ERT). The results of the OLGA 7 simulator provide appropriate source conditions for the selected dispersion models. Gaussian atmospheric dispersion model was chosen to simulate the CO2 gas dispersion behavior within the platform; it is very effective and simple. The effect of operating and design parameters (Operation Pressure, Isolation valve spacing (IVS), and Emergency response time (ERT) on the dispersion behaviors of the released gas in different leak scenarios was studied. The results showed that the emergency response time has the greatest effect on the mass of the accumulated leak (kg) and thus on the level of gas concentrations, and this effect is more pronounced for large leakage sizes. Also, the results showed that the emergency response time had no effect on levels of distance gas concentrations, but it had a significant effect on the duration of the leaking.

Efforts to stem global change include the application of new technological developments that aim to reduce atmospheric carbon dioxide (CO2) through the carbon capture and storage (CCS) of this greenhouse gas in stable geological structures. In this paper, we assess the potential risks related to the application of CCS technology and the acidification of aquatic ecosystems through CO2 enrichment. We use the multiple lines of evidence approach (LOEs) to characterize the effects of the acidification with contamination in aquatic sediments. We highlight and discuss the effects of acidification on the LOEs including contamination and mobility of contaminants in sediments, toxicity, macrobenthic community structure, in situ effects, and bioaccumulation–biomagnification processes. We further assess the results of acidification on the toxicity of organic contaminants such as antibiotics or illicit drugs like the freebase form of cocaine (crack). The main goal of using the LOE approach is to distinguish between adverse effects that are associated with contaminants and those related to acidification by enrichment of CO2 as a result of CCS technology. Previous assessments were not designed or conducted to incorporate an integrative point of view, nor did they employ a weight of evidence approach (WOE) in risk characterization and management of CCS operations and other situations related to acidification by enrichment of CO2 in the aquatic ecosystem. Based on the findings of this review, the WOE can identify the effects of the acidification on the different LOEs used for sediment quality: contaminant mobility, the adverse effects in organism under laboratory and field conditions, and the bioaccumulation–biomagnification of contaminants. The main strength in using the WOE is the ability of this method to discriminate between LOE responses associated with contamination by different organic and inorganic substances from those related to CO2 acidification itself. The WOE will significantly improve the risk assessment in areas affected by potential leakages of CO2 during CCS operations.

Global warming is a critical issue that has garnered significant attention during the last few decades. This temperature increase results from the emission of greenhouse gases into the atmosphere, most notably CO2. Carbon Capture and Storage (CCS) technology has been established as one of the most successful ways to store CO2 in underground layers and prevent it from being released into the atmosphere. However, CO2 is difficult to contain in subterranean layers subjected to high-pressure, high temperature (HPHT) conditions due to the degradation of Portland cement caused by chemical interaction with wet/dry CO2. Numerous studies have been conducted to increase the cement's resistance to CO2 attack, but limited effectiveness has been found when these methods have been evaluated under various settings. Given the distinctive properties of nanomaterials, such as high surface areas, quick contact, and resilience to heat, Nano Glass Flake (NGF) and Multiwall Carbon Nano Tube (MWCNT) were deemed to be suitable additional materials for increasing cement efficiency. On cement samples treated with NGFs and MWCNTs, a number of pre-carbonation and post-carbonation tests were performed. The pre-carbonation tests revealed that the density of NGFs-based cement remained constant with that of neat cement while the plastic viscosity increased. Additionally, it was recommended not to add more than 1wt% NGFs to the cement, as this would result in a high viscosity paste, which would negatively affect the pumping operation. On the other hand, this threshold for the viscosity of MWCNTs was roughly 0.25wt%. It was found that by using nanoparticles and employing a proper dispersion process, the cement's overall physical performance can be improved, and a lower amount of Portlandite is formed, which is critical for increased resistance to CO2 attack. In a static reactor, samples with the best pre-carbonation performance were subjected to water saturated supercritical CO2 for 56 days. It was then discovered that CO2 diffuses into cement and increases cement decomposition in the post-carbonation stage of the experiment. Samples weighing more than 0.5wt %. NGFs and 0.05 wt% MWCNTs had the smallest carbonated regions, indicating carbonated cement. However, the number of nanoparticles added to each sample resulted in a variable level of carbonation. Cement made using MWCNTs has a higher compressive strength due to its ability to manipulate CaCO3 crystal shape. NGFs-based cement, on the other hand, could be a better solution in terms of CO2 resistance. Due to their substantially lower cost than MWCNTs, it is possible to increase cement performance in CCS operations without imposing a high cost on projects.

This study estimated the availability of a ship-based carbon capture and storage (CCS) chain to investigate which would be critical components in the chain and to suggest improvement methodology for design and operation. Bo-ryeong coal-fired power plant and Ul-leung basin in South Korea are designated as the target CO2 emission source and the CO2 storage sink, respectively. The CO2 emitted from the power plant was transported by a CO2 carrier to an intermediate storage terminal and then the CO2 is moved to the basin by offshore pipeline. The ship-based CCS chain contained a capture system, a dehydration system, a liquefaction system, temporary storage tanks, a cargo handling system, a CO2 carrier, and a pumping system. The availability was estimated with the commercial code, TARO, based on the Monte-Carlo simulation method. Firstly, a chain configuration was defined for the availability estimation. Factors that might potentially cause production loss during the operation were identified, and those failure frequencies and restoration times were collected from the available literatures. Finally, the availability of the chain was evaluated. The results showed that the most significant factor was the preventive maintenance for the liquefaction system. The minor factor was a ship engine system. The tendencies of several important factors were analyzed through a sensitivity analysis.

Getting ready for carbon capture and storage in the iron and steel sector in China: Assessing the value of capture readiness

Carbon Capture and Storage (CCS) is a promising technology in the net-zero goal for global CO2 emissions. The success of CCS operations can depend on corrosion control, material selection, and integrity management, among other things. Despite extended experience with material performance in natural CO2 injection, challenges persist in safely and effectively injecting anthropogenic CO2 including impurities. Indeed, industrial impurities complicate corrosion and limit existing knowledge’s applicability. Since captured CO2 often comes from multiple industrial emitters, each CCS project need to establish CO2 specifications to ensure safe operations, given the lack of standardized guidelines. These specifications delineate upper limits for critical impurities. In a CO2 stream containing H2S, oxygen (O2) as an impurity can affect the corrosion resistance of UNS S32760 material in solution annealed and cold worked conditions, 80ksi and 125ksi grades, respectively. If the bottom-hole exhibits elevated temperatures, a high chloride content, and a low pH, O2 may trigger localized corrosion and stress corrosion cracking. Therefore, a fit-for-purpose testing program was undertaken to assess the main corrosion risks associated with the CCS project. The influence of microstructure and testing duration on corrosion behavior is discussed. The findings from this testing program are critical in determining the applicability of the material for CCS infrastructure and the development of corrosion control testing.