Eni Oko

Case study on CO2 transport pipeline network design for Humber region in the UK

Reliable, safe and economic CO2 transport from CO2 capture points to long-term storage/enhanced oil recovery sites is critical for commercial deployment of carbon capture and storage technology. Pipeline transportation of CO2 is considered the most feasible and viable option for achieving this. However, in carbon capture and storage applications, there is concern about associated impurities and huge volumes of high pressure CO2 to be transported over distances that will likely be densely populated areas. On this basis, there is limited experience for design and economic assessment of CO2 pipeline. The Humber region in the UK is a likely site for building CO2 pipelines in the future due to large CO2 emissions in the region and its close access to depleted gas fields and saline aquifers beneath the North Sea. In this paper, various issues to be considered in CO2 pipeline design for carbon capture and storage applications are discussed. Also, different techno-economic correlations for CO2 pipelines are assessed using the Humber region as a case study. Levelized cost of CO2 pipelines calculated for the region range from 0.14 to 0.75 GBP per tonne of CO2. This is a preliminary study and is useful for obtaining quick techno-economic assessment of CO2 pipelines.

Process Simulation and Analysis for CO2 Transport Pipeline Design and Operation – Case Study for the Humber Region in the UK

Abstract Carbon Capture and Storage (CCS) will play a vital role for carbon dioxide (CO 2 ) emissions reduction. Pipelines are considered the preferred method for both onshore and offshore large volumes of CO 2 transported. In the Humber region in the UK, there are two advanced proposals for CCS power station developments: the Don Valley project and the White Rose (Drax) CCS project, which were expected to provide a basis to develop a pipeline supporting a CCS cluster in this area. This paper presents a case study of the pipeline network for the Don Valley and the White Rose CCS projects, representing the possibilities in the Humber area. A model of the pipeline network was developed using the computer software package Aspen HYSYS ® and three different operating strategies were compared and discussed regarding their energy and utilities requirement. For all three operating strategies, simulation results show that energy consumption ranges from 96 to 103 kWh/t-CO 2 and cooling duty range from about 140 to 147 Mcal/t-CO 2 in a wide range of the flow rate of the CO 2 -rich stream.

Modelling of a Post-combustion CO2 Capture Process Using Bootstrap Aggregated Extreme Learning Machines

Abstract This paper presents a study of modelling post-combustion CO2 capture process using bootstrap aggregated ELMs. The dynamic ELM models predict CO2 capture rate and CO2 capture level using the following variables as model inputs: inlet flue gas flow rate, CO2 concentration in inlet flue gas, pressure of flue gas, temperature of flue gas, lean solvent flow rate, MEA concentration and temperature of lean solvent. In order to enhance model accuracy and reliability, multiple ELM models are developed from bootstrap re-sampling replications of the original training data and combined. Bootstrap aggregated ELM model can offer more accurate and reliable predictions than a single ELM model, as well as provide model prediction confidence bounds. The developed models can be used in the optimisation of CO2 capture processes.

Dynamic Modelling and Analysis of Supercritical Coal-Fired Power Plant Integrated with Post-combustion CO2 Capture

Despite the advances in power plant and CO2 capture modelling, only a few studies have presented a dynamic process model and analysis of the post-combustion CO2 capture integrated with a dynamic model of supercritical power plant. This study presents a dynamic model of a supercritical coal-fired power plant (SCPP) integrated with a dynamic model of MEA-based post-combustion CO2 capture plant (PCC). This study focuses on the impact of integrating PCC unit on the load following the mode of operation of the SCPP. The dynamic model of the PCC was validated against a pilot plant data and was scaled-up to capture the flue gas flow from 600 MWe SCPP. The SCPP model was validated with actual plant operational data for steady-state conditions at full load and at transient load ramp. The dynamic response of the integrated SCPP–PCC model due to changes in load demand is presented. The response of the following variables to changes in load level investigated includes the following scenarios: (i) the flue gas flow rates, (ii) the pulverized coal flow, (iii) the net efficiency of the SCPP, and (iv) and the CO2 capture level. The simulation shows that the CO2 capture level is very sensitive to the solvent–flue gas (L/G) ratio. In addition, steam reduction/stripper stop was analysed as a strategy for operating the SCPP integrated with PCC unit under the UK grid requirement as regards primary frequency response. The result shows that the stripper stop mechanism produces about 4.67 % MCR (~28 MWe) increase in the SCPP at full-load condition. This is however, not sufficient for the 10 % MCR required for the primary response (usually within 10–30 s).