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Monitoring and Modelling of CO₂ Storage: The Potential for Improving the Cost-Benefit Ratio of Reducing Risk

1 February 2020
Storage

The study was proposed with the intention of developing an understanding of where future research efforts in CO₂ storage technologies should be focused on in the next decade, informing the potential directions for future research in order to fully maximise the potential benefits of storage technologies to commercial-scale CCS projects.

Technical Review

CO₂stCap (Cutting Cost of CO₂ Capture in Process Industry)

1 November 2019
Capture
Costs of CCUS

The CO₂StCap project (Cutting Cost of CO₂ Capture in Process Industry), led by SINTEF, was a research initiative (2015-2019) funded by the Norwegian CLIMIT-Demo programme via Gassnova and the Swedish Energy Agency. The CO₂StCap research partners were SINTEF, the University of South-Eastern Norway, Chalmers University of Technology, RISE, and Swerim AB. The industries involved were SSAB, Elkem AS, Norcem Brevik AS, and AGA Gas AB. IEAGHG and GCCSI supported the project. The CO₂StCap project investigated CO₂ partial capture configurations for cement, pulp and paper, steel, and silicon for solar cells industries. The CO₂ capture technology investigated in this project was a MEA-based chemical absorption system, which includes an optimized rich-solvent splitting and absorber inter-stage cooling. The capture rates considered are dependent on the inputs of the specific cases, such as plant characteristics, CO2 stacks, CO2 concentration in the flue-gas to be treated, and supply of heat/energy. The CO₂StCap project contained a transparent cost assessment, which includes the capital and operational expenditures (CAPEX and OPEX) for retrofitting cases. The main cost metric used in this study is the CO₂ capture cost (€/tonne of CO₂ captured) and the main elements are described in detail. Steam generation for the CO₂ capture system was identified as a key cost element. The steam sources investigated were: steam produced from the excess heat; from a new boiler; and from a low-pressure bleed from existing steam cycles. Other key cost elements identified in this study are the plant lifetime and rate of return. The CO₂StCap project also investigated the use of biomass in different sectors and hydrogen in the steel industry.

Technical Review

Integrated GHG accounting guidelines for CCUS

1 November 2019
Policy & Regulation

This report sets out accounting guidelines for measuring greenhouse gas (GHG) emissions and emissions reduction effects arising from technologies involving carbon dioxide capture, utilisation and geological storage (CCUS).The guidelines apply a project- and product-based approach to measure GHG emission reduction effects, based on comparing the emissions for a CCUS activity with the emissions from a comparable activity delivering the same product or service.A modular approach is applied. Firstly, users calculate the GHG effects arising from the capture (and transport) of CO₂ based on the avoided emissions from providing the same service or product as output from the CO₂ source facility, but without CO₂ capture.The resulting estimate of GHG effects from CO₂ capture is carried forward to the utilisation or storage step. In this subsequent step, the GHG emissions from providing the same service without using captured CO₂ is estimated and compared to the GHG emissions of providing the service using captured CO₂. This provides an overall estimate of the cradle-to-gate GHG effect of CCUS activities.Additional guidance is provided on cradle-to-grave assessment, although this is not the primary focus of these guidelines – the Guidelines focus on annualised GHG emissions accounting cycles rather than whole life emissions analysis.

Technical Report

CO₂ capture in LNG

1 October 2019
Capture
Costs of CCUS

Natural gas demand is forecasted to grow continuously for the next 10 years, playing a vital role in the global energy mix in 2030. in the specific case of liquefied natural gas, projections indicate a continued upward growth. The majority of near-term growth in liquefaction capacity is likely to happen in North America and Australia, although a number of other projects have the potential to add significant liquefaction capacity in the long term as well.

Technical Report

Further Assessment of Emerging CO₂ Capture Technologies for the Power Sector and their Potential to Reduce Costs

1 September 2019
Capture
Costs of CCUS

CSIRO was commissioned by IEAGHG to provide a comprehensive assessment of emerging CO2 capture technologies for the power sector and their potential to reduce costs. The objectives of this technical study were:  <ul> <li>to update the CO2 capture benchmark technology and its enhancement over the 30w.t.% MEA-based chemical absorption</li> <li>to review the CO2 capture technologies, their current status and trajectory</li> <li>to assess the potential of emerging CO2 capture systems to reduce costs (LCOE) and identify risks and barriers for those on the path to TRL 9</li> <li>to assess techno-economically a number of selected CO2 capture technologies for coal and gas-fired power plants.</li> </ul>

Technical Review

Guide to Front End Engineering Design studies for selected CO₂ Capture and Storage Projects

1 September 2019
Capture
Storage

This review aims to assess the current understanding on reducing emissions from flaring in the oil and gas industry and to review literature on both the quantification of emissions and current mitigation strategies. IEAGHG published a technical review 2017-TR7 (Oct 2017) which studied emissions along the natural gas supply chain but flaring emissions were not included. This review aims to follow on from 2017-TR7 as a supplementary review on flaring emissions.

Technical Report

Proceedings: Workshop on Representing Carbon Capture Utilisation and Storage in Energy Systems Models

1 August 2019
Event Proceedings

The USDOE’s Office of Fossil Energy convened a workshop on 17-19 October 2018 in College Park, Maryland, USA, to provide a forum to review and exchange the latest understanding of carbon capture utilisation and storage (CCUS) and to improve the modelling approaches and representation of CCUS in energy systems models (ESMs) and Integrated Assessment Models (IAMs). This was the second workshop on this theme, following a previous workshop also hosted by US DOE-FE on 3-4 April 2017 in Washington DC, USA. This second workshop was designed to grow and expand the number of research groups with expertise in up-to-date modelling of advanced fossil technologies and related market impacts, including application of US National Energy Technology Labs (NETL) cost and performance baseline data and CCUS expertise, tax implications of 45Q, EOR market feedback and information on international markets. It also sought to create a community of practice and to link CCUS technical experts with modellers and analysts.

Technical Report

CCS in Energy and Climate Scenarios

1 July 2019
Industry Insights

The purpose of IAMs is to quantify the interactions and trade-offs between societal demands for energy, economic and environmental services, using a systems approach. These systems are typically the energy system, the economy, the earth-land system, the water system and atmospheric climate system, although every IAM does not necessarily include all these systems and have varying

Technical Report

6th CCS Cost Workshop

1 July 2019
Costs of CCUS
Event Proceedings

The sixth meeting of the CCS Cost Network Workshop was held on March 19-20, 2019 at the Electric Power Research Institute (EPRI) headquarters in Palo Alto, California, under the auspices of the IEA Greenhouse Gas R&D Programme. The purpose of the workshop is to share and discuss the most current information on the cost of carbon capture and storage (CCS) in electric utility and industrial process applications, as well as the outlook for future CCS costs and deployment. The workshop also seeks to identify other key issues or topics related to CCS costs that merit further discussion and study.

Technical Report

The Shell Quest Carbon Capture and Storage Project

1 June 2019
Capture
Storage

In late August 2015, Shell Canada began sustained, commercial-scale operation of the first-ever CO₂ capture facility at an oil sands bitumen or heavy oil upgrader in the world, as well as transportation and storage of the carbon dioxide to a nearby geological storage site. This remarkable facility is situated near Edmonton, Alberta, Canada. This report explores the journey of the Shell Quest Carbon Capture and Storage Project team and its partners, and will provide valuable insights to other heavy oil upgraders and oil refineries globally that seek to reduce their lifecycle greenhouse gas emissions through deployment of CCS technologies and infrastructure.

Technical Report

Review of Fuel Cell Technologies with CO₂ Capture for the Power Sector

1 April 2019
Capture

DOOSAN U.K. was commissioned by IEAGHG to provide a comprehensive techno-economic review on MCFCs and SOFCs for the power sector. The objectives of this technical study were:   <ul><li>Deliver a literature review on MCFCs and SOFCs, identifying available configurations, status of development, applications and gaps to reach economically viable solutions </li><li>Supported by data from the literature, provide a techno-economic evaluation on selected cases and compare to a number of reference cases with and without a benchmark CO₂ capture system (chemical absorption with Cansolv technology) </li><li>Identify key parameters and areas impacting the price of implementing those technologies in the power sector as CO₂ abatement systems </li><li>Describe barriers and challenges to be addressed for SOFCs and MCFCs to achieve commercial application</li></ul>

Technical Report

Towards Zero Emissions CCS from Power Stations using Higher Capture Rates or Biomass

1 March 2019
Capture

To-date, capture technology developers have largely focused on designing plant for CO₂ capture rates of 85% to 90%, leaving 10-15% of the emissions uncaptured, which are usually referred to as residual emissions. In a “well below 2°C” scenario, it is projected that net zero carbon emissions would be required by early in the second half of this century. A review of the literature indicated that there were no technical barriers to increasing capture rates in the three classic CO₂ capture routes (post-, pre- and oxyfuel combustion) and with the broad suite of CO₂-capture technologies currently available or under development. A techno-economic analysis of a standard PCC process applied to both coal- and gas-fired power plants revealed that, with dedicated process design, the additional costs of achieving essentially zero CO₂ emissions were quite modest in comparison with the costs of achieving 90% CO₂ capture. For coal-fired power stations, the analysis found that using biomass co-combustion (10% biomass) combined with a standard PCC process (90% CO₂ capture) was the lowest cost option.

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