5.3 Co2 Intermediate Storage Philosophy

KCP-EEN-CSO-DPR-0001 Rev.: 03

Project Title: Kingsnorth Carbon Capture & Storage Project of 3

Document Title: CO2 Intermediate Storage Philosophy

Kingsnorth CCS Demonstration Project The information contained in this document (the Information) is provided in good fai th. E.ON UK plc, i ts subcontractors, subsidiaries, affi l iates, employees, advisers, and the Department of Energy and Cl imate Change (DECC) make no representation or warranty as to the accuracy, rel iabil i ty or completeness of the Information and neither E.ON UK plc nor any of i ts subcontractors, subsidiaries, affi l iates, employees, advisers or DEC C shal l have any l iabil i ty whatsoever for any direct or indirect loss howsoever arising from the use of the Information by any party .

CO2 Intermediate Storage Philosophy

Table of Contents

1. Scope and Functional Requirements

2. Assumptions

3. Design Requirements

4. Mandatory References

5. Supporting References





1. Scope and Functional Requirements This design philosophy considers the possibility of a future, potential requirement to install an onshore CO2 intermediate storage facility at Kingsnorth when the CO2 is introduced into the pipeline in dense phase.

Genesis Oil & Gas Consultants have carried out modelling in FEED 1A confirming that it will be possible to re-start injection of CO2 into the already pressurised pipeline after a shutdown of the CO2 capture plant when the CO2 is injected in gaseous phase. The shutdown period can be as long as 120 hours (5 days) when the reservoir is at low pressure, being subsequently reduced to 55 hours (2.3 days) when the reservoir approaches its maximum pressure consistent with pipeline operation in gaseous phase. These outcomes correspond to the case when the CO2 continues to flow at a reduced rate into the reservoir after the capture plant has been shut down (i.e. the Hewett choke is left open). In both cases, it has been confirmed that CO2 intermediate storage is not required when the CO2 is injected into the pipeline in the gaseous phase [S1].

In addition, it has been confirmed by Baker RDS that CO2 will be injected into the pipeline in the gaseous phase only during the expected term of the demonstration period (i.e. all flow into the pipeline and field during the DECC demonstration will be conducted in the gaseous phase) [S2]. Therefore, onshore CO2 storage will not be required during the DECC demonstration period of the project.

2. Assumptions It is assumed that substantial intermediate CO2 storage will probably be required before a pipeline transport system can be converted to dense phase operation (beyond the demonstration period). The amount of intermediate storage required will be determined by giving consideration to:

1. Overall flow rate from an approximate 90% capture of CO2 from a fully developed, newly replaced Kingsnorth coal-fired power station (assumed for the purpose of this study to be 1.6 GWe from two power trains).

2. Flexibility of operation will be required of the full carbon capture and storage (CCS) chain (e.g. two shifting, regular stop/start, regular turndown and turn-up, frequency response duty according to current grid code requirements).





3. Minimum and maximum stable operation of the compression plant (including dehydration unit).

4. Eventual grid code compliance scenarios resulting from the UK Government’s energy market review will change. Designers will need to know the exact future grid code compliance requirements in order to design intermediate storage that will provide sufficient flexibility.

5. Cost of emissions resulting from the UK Government’s energy markets review. In order to test the feasibility of different options for intermediate storage and to determine an affordable level of operational flexibility, designers will need to understand what the future cost of emissions will be. There is also a nexus between the cost of emissions and the constraints imposed on operations by future EPR requirements and designers will need to fully understand the cost and effect of both.

6. Payments that will be made to secure flexibility and capacity in new power generation assets during the UK Government’s energy markets review will need to be understood.

3. Design Requirements No technical work on intermediate CO2 storage for dense phase operation has been carried out in FEED 1A as it will not be required during the demonstration phase of the project.

Design requirements will be developed in a separate project beyond the demonstration period and should consider potential opportunities to combine CO2 capture with enhanced oil recovery (EOR) applications. This combination could potentially reduce the complexities to accommodate flexible operation of the CCS chain while providing extra revenue to support the project.

4. Mandatory References None

5. Supporting References [S1] KCP-GNS-FAS-DRP-0003 Transient Analysis – Start-Up

(Pipeline) [S2] KCP-RDS-CWE-REP-1002 Vertical Flow Performance

5.3 Co2 Intermediate Storage Philosophy

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