Gassco (Norway)

To maximise economies of scale of future CO2 transport infrastructure, new CO2 pipelines within the carbon capture utilisation and storage (CCUS) value chain, should ideally have excess capacity to satisfy future transportation demand. However, in scenarios where booster compressors cannot be employed along the pipeline, the rise in pipeline mass flow rate over time culminates in higher energy consumption of upstream compression/liquefaction. This work explores the optimisation of various CO2 pressurisation pathways and assesses their flexibility in handling a variability in pipeline mass flow rates whilst delivering a captured CO2 stream at a fixed final pressure of 100 barg. The study is based on the Dunkirk 3D Project, which has a planned nameplate capture capacity of 1 MtCO2/y, with other CO2 point sources taking up additional pipeline utilisation capacity. Two categories of CO2 pressurisation pathways are considered, gas compression and subcritical liquefaction and pumping. These pathways are optimised to enable a fair comparison, considering the number of compression stages, compression ratio, and cooling/liquefaction system. Modelling results indicate that the temperature of the cooling utility has the greatest influence in reducing the overall work duty and sensitivity to a variability in pipeline mass flow rate. Furthermore, the utilisation of 5 °C seawater as a cooling and liquefaction utility reduces the work duty of the conditioning process by 25.4% and requires fewer compression stages relative to conventional gas compression utilising cooling water at 30 °C.

Abstract Process Safety assurance is built on the premise that all Safety Critical Elements [SCEs] / HSE Critical Equipment & systems [HSECESs] are operated and maintained so that they are functionally available on demand to prevent / mitigate / control process safety incidents. This means that, HSECES management is fundamental to process safety assurance, which is the essence of ADNOC COPV6-01, Verification of Technical Integrity. GASCO Technical Integrity or HSECES Assurance Management process is being continuously improved or optimized to make the process robust and practical incorporating the lessons learnt. GASCO embarked on a journey to build assure management of HSECES into the day-to-day operations at all of its operational sites almost seven years ago and is sharing the best practices to hazardous industries through ADIPEC, the world's largest oil & gas conference. This paper highlights the operationalization of HSECES management for operating plants in an integrated manner, in compliance with ADNOC COP6-01. The clear value-adding differentiators of this model includes the Technical Authority process, HSECES performance test report automation and maintenance of this model for new projects and changes to existing plants. This pragmatic and optimized model brings in an integrated Technical Integrity approach to the region.

Abstract Both field experience and lab data indicate that the corrosion rate in pure dense phase CO2 is near zero if no free water is present. It is not confirmed that this also applies when other contaminants like SOx, NOx, H2S and O2 are present in moderate amounts. In a pipeline network with different type of CO2 sources, the comingling of streams with various impurities can give a very complex mixture, and side reactions like 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 more and more uncertain what will happen when the concentration of contaminants including water increases. The paper addresses these issues and discusses recent results obtained in corrosion and partitioning experiments carried out in flow loops and autoclaves.

Abstract In consideration of lump-sum EPC (Engineering, Procurement and Construction) oil & gas Project needs and potential benefits of Client source inspection, a review of recent experience in Client Third Party Inspection (TPI) involvement at source on EPC Projects has been conducted. The review of Client TPI involvement at source has considered experience on several large EPC Projects. This paper summarizes the findings of the review and recommendations for improvements. Four key themes that run thorough these recommendations are as follows: Improvements to the criteria for purchase order selection for Client source inspection involvement.Improvements to the criteria for inspector selection.The need for the Client Quality Manager to remain engaged with the technical scope of inspection activities.The importance of technical definition of inspection scope and requirements for inspection reporting. The scope of this paper does not include requirements for specialist engineering witness of final factory acceptance or performance testing.