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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

The CCS Project at Air Products’ Port Arthur Hydrogen Production Facility

1 December 2018
Industry Insights

In April 2013, the first commercial-scale, steam methane reformer hydrogen production facility incorporating vacuum-swing adsorption carbon capture gas separation technology began full-scale operation at Air Products’ facilities located on the site of the Valero Port Arthur Refinery in Texas, USA. This report summarizes the experience of Air Products and its partners that will provide valuable insights to other petroleum refining and petrochemical industrial facilities that wish to reduce their lifecycle greenhouse gas emissions through CCUS.

Technical Report

Flaring Emissions Quantification and Mitigation

1 December 2018
Capture

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

IEAGHG Modelling and Risk Management Combined Network

1 November 2018
Event Proceedings
Storage

IEAGHG’s combined Modelling and Risk Management Network, hosted by the EERC, took place in Grand Forks, North Dakota between 18th and 22nd June 2018. These meetings bring together leading experts from research and industry to discuss the latest work and developments, with over 30 speakers and 71 attendees representing 8 countries. The theme for the meeting was ‘How advances in modelling and risk management improve pressure management, capacity estimation, leakage detection and the prediction of induced seismicity’. Sessions included project updates, the application of oil and gas production experience, modelling capacity, unconventional reservoir risk assessments and active pressure management. The third day focused on conformance and regulation with a keynote presentation by Lynn Helms from the North Dakota Industrial Commission on Class VI well regulations.

Technical Report

Well Engineering and Injection Regularity in CO₂ Storage Wells

1 November 2018
Storage

This project focuses on collecting industry experience on the drilling, completion, regularity and interventions of CO₂ wells. The aim for the report was to compare methodologies and techniques used for handling CO₂ compared with those required for hydrocarbon extraction. This has allowed for a comparison to be made to the research already conducted on CO₂ well integrity and monitoring techniques. The study will investigate whether conditions experienced during CO₂ handling operations were predicted from modelling and experimental work and the effectiveness of linked risk assessments.

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

3rd International Workshop on Offshore Geologic CO₂ Storage

1 August 2018
Event Proceedings
Storage

This workshop came about to address a recommendation from the CSLF on offshore CCS. This 3rd International Workshop on Offshore CCS took place on 3-4 May, organised by the Bureau of Economic Geology (BEG) in collaboration with IEAGHG and others, and hosted by the Research Council of Norway in Oslo, with support from SANEDI and CSLF.The aim of the workshop series is to facilitate sharing of knowledge and experiences among those who are doing offshore storage and those who are interested, and to facilitate international collaboration on projects. Over 60 attendees from 8 countries participated in this 3rd workshop.The agenda included: How to learn from learnings?; Value Chains for Offshore; Infrastructure re-use; Monitoring offshore CO₂ storage/EOR; Offshore CO₂ storage resource assessment; Project updates; Standards and Regulatory Frameworks; and Brainstorming towards an international collaborative project.

Technical Report

Re-Use of Oil & Gas Facilities for CO₂ Transport and Storage

22 June 2018
Storage
Transport

Our recent study ‘Case Studies of CO₂ Storage in Depleted Oil and Gas Fields’ (2017-01) concluded that CO₂ storage in depleted fields would not only be viable with potentially lower risk but could also be relatively cost effective, providing important intermediate-scale storage resources. The report highlighted that re-using an O&G fields would be beneficial as “there would likely be cost savings over saline aquifer sites, particularly in the characterisation stages (where there is the advantage of production history and proved hydrocarbon retention to reduce uncertainty in containment and capacity)”.

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.

Technical Report

5th Cost Network Proceedings

1 March 2018
Costs of CCUS
Event Proceedings

The purpose of the CCS Cost Workshops is to share and discuss the most currently available 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

GHG Accounting for CCU Technologies - Characterising CCU technologies, policy support, regulation and emissions accounting

1 March 2018
Policy & Regulation
Utilisation

Over recent years, interest in CO₂ capture and utilisation (CCU) from policy-makers, industry and academics has increased dramatically, although uncertainty remains regarding the technology’s true potential to contribute towards wider greenhouse gas (GHG) emissions reduction goals. A range of views have been expressed in these contexts, but on the whole it remains largely speculative and unproven. Consequently, it is difficult to provide firm opinions on whether CCU technologies can make a meaningful and lasting contribution to tackling climate change. This report provides an assessment of the range of views presented by various stakeholders, and attempts to establish an empirical evidence base upon which to qualify the views and opinions expressed.Additionally, the key way to gain a clearer understanding of the potential for CCU technologies to reduce GHG emissions is to assess the overall energy and carbon balances for different CCU processes, and to take a view on how and whether these could make a contribution to GHG emission reductions. In other words, as noted by the Intergovernmental Panel on Climate Change (IPCC) in its 2005 Special Report on Carbon Dioxide Capture and Storage (SRCCS) ‘further study of the net energy and CO₂ balance of industrial processes that use the captured CO₂ could help to establish a more complete picture of the potential of this option’. Such detailed studies have, at best, only partially been carried out and are heavily reliant on the assumptions made in the analysis. Thus, IEAGHG has commissioned Carbon Counts (UK) Ltd to characterise CCU technologies, as well as their policy support, regulation and emissions accounting.

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