The First International Forum on
Transportation of CO2 by Pipeline

1-2 July, 2010
Newcastle, UK

Technical Programme

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Thursday 1 July

by Prof. Jon Gibbins, Professor of Power Plant Engineering and Carbon Capture, Institute for Materials and Processing, School of Engineering, The University of Edinburgh, Edinburgh, UK

by Russell Cooper, National Grid Gas Transmission, Warwick, UK

by James Watt, Technical Manager - Renewable Energy/CCS
AMEC Power and Process, Europe, Darlington, UK

by Yannis Savidis, HM Specialist Inspector, Gas and Pipelines, HSE, Nottingham, UK, and Mike Bilio, HM Specialist Inspector, Offshore Safety Division, HSE, Bootle, UK

HSE has commissioned research work to compare carbon dioxide and natural gas pipelines in terms of hazard range and risk to determine the appropriateness of carbon dioxide being regulated as a dangerous fluid under the Pipeline Safety Regulations (PSR). HSE is also involved in research to examine the risk control and associated risk management of high pressure CO2 transportation by pipeline. This presentation considers proposals for modification to PSR in light of current findings, explores the current regulatory regime and expectations for CO2 pipeline design, operation and risk management.

by Prof. Alex Kemp, Director, Aberdeen Centre for Research in Energy Economics and Finance, University of Aberdeen Business School, Aberdeen, UK

by Saulat Lone, Sui Northern Gas Pipelines Ltd, Pakistan, Dr Tim Cockerill, ICEPT, Imperial College London, UK, and Prof. Sandro Macchietto, Department of Chemical Engineering, Imperial College London, UK

by Dr Andrew Cosham, Atkins Boreas, Newcastle, UK

The past provides valuable lessons for the present. In the 1960s and 70s, the pipeline industry undertook extensive research work to solve the problem of fracture propagation in lean and rich gas pipelines, and the result was semi-empirical methods for estimating the toughness required to arrest a fracture, based on the drop-weight tear test and the Charpy V-notch impact test. The previous research informs the work that is required to solve the same problem in the next generation of CO2 pipelines that will be required for the successful implementation of carbon capture and storage. In this paper, the similarities and differences between lean and rich gas pipelines, and CO2 pipelines are discussed, and an outline of the research work that is required to solve the problem is presented.

by Prof. Haroun Mahgerefteh, Professor of Chemical Engineering, Department of Chemical Engineering, University College, London, UK

by Prof. Shuji Aihara and Kei Misawa, Department of Systems Innovation, Graduate School of Engineering, The University of Tokyo, Tokyo, Japan

Unstable crack propagation and arrest behaviours in CO2 pipelines are analysed by a numerical simulation model developed by the authors. Interaction between crack propagation and decompression of fluid in pipeline is important, especially in CO2 pipelines due to complex thermodynamic behaviour of CO2. The model takes account of the interaction and simulates the transient behaviours of crack initiation, propagation, and arrest. The paper shows how fluid impurities affect crack propagation and arrest behaviours, and discusses the crack arrest toughness values required for CO2 pipelines.

by Robert M Andrews, BMT Fleet Technology, Loughborough, UK, Dr Jane V Haswell, Pipeline Integrity Engineers, Newcastle, UK, and Russell Cooper, National Grid Gas Transmission, Warwick, UK

A hypothetical concern has been raised that leaks in a CO2 pipeline could escalate to a propagating fracture due to the potentially large temperature drop associated with the expansion of either gaseous or dense phase CO2 to ambient conditions. It is suggested this local cooling would lower the pipe wall temperature to an extent that a brittle fracture would initiate followed by a transition to a propagating fracture. Although such a mechanism could theoretically occur in natural gas pipelines, there is increased concern for CO2 transport because of the different thermodynamic behaviour of the contents, particularly for dense phase transport.

This paper critically reviews the literature associated with this postulated failure mechanism and other studies on the cooling of cracks and holes by escaping fluid. It is concluded that pipelines constructed to modern standards are not at risk. Limited crack extension may occur when the leak is through a “tight” crack in a material of low toughness. However, the crack will arrest as it enters warmer material remote from the leak. Escalation to a propagating fracture can be controlled using methods which are widely used and understood in the pipeline industry.

by Arne Dugstad and Bjørn Morland, IFE, Norway

Both field experience and laboratory data indicate that the corrosion rate in pure dense-phase CO2 is near zero if no free water is present. It is expected, but not confirmed, that this also applies when other contaminants such as SOx, NOx, H2S and O2 are present in moderate amounts.

In a pipeline network with different types of CO2 sources, the commingling of streams with various impurities can give a very complex mixture and side reactions such as oxidation and decomposition of impurities can be foreseen. An important issue is how the contaminants partition between the various phases during pressure reduction and when free water is present. The corrosion mechanisms under these conditions are not very well understood, and it becomes increasingly uncertain what will happen when the concentration of contaminants, including water, increases. The paper will address these issues and discuss recent results obtained in corrosion and partitioning experiments carried out in flow loops and autoclaves at IFE.

by Colin McKinnon, J P Kenny, Staines, and Antonio Caraballo, WG Integrity Management, London

Successful carbon capture projects will require safe and economic transport of CO2. This paper describes how the various CO2 pipeline design, material and operational technical challenges can be overcome, including:

  • code and regulatory requirements -  code coverage of CO2
  • what are the challenges for obtaining a licence to operate?
  • design issues - design factors and population proximities
  • process issues - phase issues and flow modelling
  • welding and material issues such as ductile fracture at low temperature
  • safety philosophy differences from gas pipelines
  • risk assessment and dispersion modelling
  • operating philosophy needed to manage swing within and outside the dense phase envelope
  • pump technology - do we need compressors as backup during low pressure conditions?
  • integrity monitoring requirements
  • leak-detection methodologies
  • existing CO2 pipelines

The paper identifies the technology gaps that need to be filled in order to deliver cross-country and subsea CO2 pipelines in Europe or the Middle East, and draws on recent CO2 pipeline design experience in the UK, Middle East, and USA.

The North East of England Branch of the Professional Institute of Pipeline Engineers (PIPE) will be delighted to welcome aboard forum delegates, regional members and their guests for a cruise along the river Tyne. This will be an unrivalled way to experience the famous riverside and as an added engineering treat it has been arranged for the Gateshead Millennium Bridge to be lifted in our honour. Complimentary drinks will include a wide range of region ales. Food will be provided by the highly regarded Kisii East African/Indian restaurant of Whitley Bay.

The mooring is on the North Bank a short walk from the Gateshead Hilton. Embarkation will start from 18:30. Sailing will be at 19:00. Return is at 21:00. Final disembarkations will be at 22:00.

PIPE is the international membership organization organization for those who work in the design, construction, operation, and maintenance of oil and gas pipelines. For information on the range of discounts and benefits available to PIPE members visit www.pipeinst.org.

Friday, 2 July

by Dr Tim Hill, Technical Head, Environmental Sciences & Climate Change Sustainable Energy, E.ON Engineering, Nottingham, UK

Seen as a delivery system taking a refined product from an industrial process to a storage facility, the CO2 pipeline must be designed to meet the joint requirements of low-risk of containment failure and flexibility in volume flow, whilst keeping costs to a minimum. With a wide range of capture technologies potentially available to create a concentrated CO2 stream, the chemical composition of the CO2 and its physical characteristics may vary considerably. This presentation will provide an overview of the range in CO2 quality that could be expected from different CO2 capture plant and other factors due to plant operation that might impact on the design requirements of CO2 pipelines.

by Kaare Helle, Kim Johnsen, Sigbjørn Røneid, and Frøydis Eldevik , DNV, Hovik, Norway

A unified Recommended Practice (RP) for safe and reliable design, construction, testing, operation and maintenance of steel pipelines for transmission of CO2 has been developed through the CO2PIPETRANS Joint Industry Project (JIP). The RP applies to pipelines for large scale transmission of CO2 and is intended as a supplement to existing recognized standards for both onshore and submarine pipelines. 

The fundamental properties of CO2 and CO2 compositions relevant in the context of CCS are covered, and the RP identifies main concerns associated with various CO2 sources and the typical impurities present. Particular challenges related to CO2 streams as a medium are identified and guidance’s provided to meet these challenges both considering compliance with existing pipeline standards and issues related to public acceptance and safety.  

A set of knowledge gaps was identified in the development of the recommended practice. The second phase of CO2PIPETRANS will perform at set of R&D activities to close these knowledge gaps and issue an updated version of the DNV Recommended Practice in 2011. This paper also delineates the planned and ongoing activities of CO2PIPETRANS phase 2.

by Dr Tim Cockerill, ICEPT, Imperial College, London, UK, Dr Naser Odeh, AEA Technology (and formerly University of Reading), Reading, UK and Scott Laczay, ICEPT, Imperial College, London, UK

Headline figures suggest CCS technology will capture 90% or more of the CO2 produced by a power plant. While this may be true at the stack, on a full lifecycle basis the GHG savings offered are more modest thanks to significant resource consumption in upstream and downstream processes. Our analysis suggests lifecycle GHG emissions can be reduced to approximately 170 gCO2/kWh for an integrated gasification combined cycle (IGCC) plant with 90% capture efficiency. This still represents approximately an 80% saving compared to conventional coal plant, but is considerably higher than the better performing renewables such as wind that produces only 10-20 gCO2/kWh in good locations

This paper examines the origin and importance of upstream and downstream CCS GHG emissions, in particular identifying those associated with transport processes. Sensitivity studies investigate which major design and operational characteristics of a CCS system are likely to have an important impact on transport GHG emissions. Drawing on these results, high level strategies for emission minimisation from transport are also discussed.

The scope for combining biofuels with CCS in order to improve lifecycle performance is considered. In principle BioCCS could produce a system with overall negative atmospheric GHG emissions. However that potential is constrained by emissions arising from the production and transportation of biofuels.

by Shiladitya Paul, Richard Shepherd, Amir Bahrami, and Paul Woollin, TWI, Abington, UK

Understanding materials’ behaviour and assessing their integrity when in contact with supercritical CO2 is crucial to the success and sustainable implementation of carbon capture and sequestration plans. Of critical importance for the successful and cost effective operation of existing and new-build, infrastructure components, is quantifying materials’ integrity in representative high pressure and supercritical CO2. This will enable confident materials selection, safe operation and accurate remaining life assessment to avoid the consequences of unexpected failure, as well as removal and replacement.

One of the most critical technical issues is quantifying degradation of different transport components, including pipes, pumps and valves, in CO2 as a high pressure gas or as a supercritical fluid, particularly in the presence of impurities. Although there is considerable experience of testing materials in lower pressure CO2, there are no standard test methods and few data for supercritical CO2. This paper explores the state-of-the-art in this field and highlights the areas of technology gap. It further describes some of the ongoing work at TWI to address some of the critical issues which should be resolved to allow confident new build design or rerating of existing infrastructur

by Patricia Seevam, BP, Sunbury on Thames, UK

by Monica Håvelsrud, Principal Consultant Flow Services, SPT Group AS, Stavanger, Norway

by Dr Harsh Pershad, Senior Consultant, Element Energy Ltd, Cambridge, UK

by Jeff Chapman, Chief Executive, Carbon Capture & Storage Association, London, UK

 


Organized by:

Clarion Technical Conferences

Tiratsoo Technical

Supported by: Newcastle University  
  PIPE Pipelines International The Journal of Pipeline Engineering