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Agenda Workshop on Hydrogen Production with CCS

21 February 2020
Capture
Event Proceedings

Hydrogen is a key raw material to other energy intensive industries. Globally, nearly 90% of the hydrogen produced industrially is consumed by the ammonia, methanol and oil refining industries. Moreover, hydrogen could soon play a significant role in the decarbonisation of power, space heating (i.e. industrial, commercial, building and residential heating) and transport fuel (i.e. use of fuel cell vehicles). Although the steam methane reformer route (SMR) is the leading technology for H2 production from natural gas or light hydrocarbons, there are other mature and emerging alternatives. Similarly, while increasing the process efficiency has shown a CO₂ emissions reduction of nearly 10%, CCS has been identified as a key strategy to cut down CO₂ emissions from hydrogen production. Against this background the Carbon Sequestration Leadership Forum (CSLF) decided to map activities on hydrogen production with CCS in member states and elsewhere. One conclusion of that exercise was to hold workshop with other organisations. A steering committee was formed to organise this workshop, held on November 6th 2019, and hosted by EDF and Club CO₂. This workshop was held for one day, devoted to a plenary session addressing three general topics, and including 90 attendees from 19 countries. Each session included several invited presentations, followed by a discussion among the workshop attendees. This document presents brief summaries of the three plenary sessions topics and one break-out session where all attendees were able to contribute.

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 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

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.

Technical Report

Sustainability in Petrochemicals

1 February 2019
Capture
Industry Insights

This report investigates a unique combination of these industry drivers on the historic, current and future status of the petrochemical industry to gain insight into the sustainability of petrochemicals. Three categories of petrochemicals are subject to analysis, namely methanol, olefins and ammonia/urea. For each of these petrochemicals, the following series of studies are formed and analysed in aggregate to gain insight in to the sustainability prospects of the industry:  <ul><li>An assessment of the historic and current status of market trade, including trends in end-uses, feedstocks, demand, production and international trade. Demand projections for each chemical are made based on collected data.</li> <li>Process engineering characterisation of the current and low carbon alternative routes and feedstocks to produce the key petrochemical productions.</li> <li>Environmental life cycle assessment of the various feedstocks and production methods for each petrochemical and a contribution analysis of the key environmental impacts.</li> <li>Market projection of petrochemical production and technology mixes for a key region China, for the time period 2010 – 2050.</li> <li>A series of expert stakeholder interviews on views of how the petrochemical industry may progress in terms of demand, costs, environmental impacts and policy drivers.</li></ul>

Technical Report

Flaring Emissions Quantification and Mitigation

1 December 2018
Capture

Technical Report

Cost of CO₂ capture in the industrial sector cement and iron and steel industries

1 September 2018
Capture
Costs of CCUS

This technical review is part of the IEAGHG concern on CCS in the industrial sector, where we have covered several industries and technical aspects through our previous reports. We will continue monitoring this sector and the forthcoming developments on CCS systems.

Technical Report

Effects of Plant Location on the Costs of CO₂ Capture

1 April 2018
Capture
Costs of CCUS

In recent years, IEAGHG has published several studies that address the application of CCS to coal and natural gas-fired power plants. The studies are based on a hypothetical site in the Netherlands. However, while Europe may be one region where large-scale power plants with CCS are built, there is even greater potential for CCS in regions where coal consumption is high and increasing or where emission reduction targets would require CCS to also be considered for gas-fired power stations. While very often, the cost of CO₂ capture is cited as a single value or as a range, the performance and costs of plants with CO₂ capture will be different at different locations – and there is currently a shortage of information calculated on a consistent basis, particularly for emerging economies.The key factors that influence the costs of capture, how these vary regionally and how the costs of capture varies regionally would be of enormous interest. For many, greater granularity in the regional differences in costs would be of value. For countries, such information could help them develop their national and international energy policy to greater effect, particularly where it relates to CCS. Similarly, industry could better identify markets and better target its spend on technology development and deployment. Incomplete information can lead to flawed analysis and result in poorer decision making. Considering these matters, the IEAGHG ExCo felt a study to investigate how the cost of CO₂ capture varied for different locations was warranted. Following a competitive tender, Amec Foster Wheeler (now Wood Group), Milan, were commissioned to undertake the study.

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