TVU CCS Pre FEED WP6 Offshore Transportation to Storage Study

Transcription

1 TVU CCS Pre FEED WP6 Offshore Transportation to Storage Study Concept Report Author: Progressive Energy Ltd This report contains TVU Category 3 information A1 Issued for Design 23/01/15 26/01/15 26/01/15 R1 Issued for Comment JMA 08/01/15 DJH 09/01/15 RKE 09/01/15 Issue Rev Issue or Revision Description Origin By Date Chkd By Date Appd By Date Progressive Energy Ltd MS986 1 of 87 i-xx-05905

2 Revision Changes Notice Rev. Location of Changes Brief Description of Change Changes within the document from the previous issue are indicated by a change triangle List of HOLDS HOLD No. Location of HOLD Reason for HOLD MS986 2 of 87 i-xx-05905

3 Table of Contents Revision Changes Notice... 2 List of HOLDS... 2 Table of Contents... 3 Glossary of Terms Executive summary Introduction Project Background Overarching TVU Project brief Purpose of the CO 2 Offshore Transportation to Storage Infrastructure Key Volumes and Parameters CO 2 Network Requirements Specific Project Objectives Process undertaken Overview of screening and optioneering process Overview of Concept development process Summary of selected options for concept development and costing Concept 1: Route to the NGC Storage Complex 5/ Concept definition Summary of key engineering performance parameters High level operability review Concept 2: Route to Shell Goldeneye Storage Complex Concept definition Summary of key engineering performance parameters High level operability review Conclusions Appendix A Overall Offshore Infrastructure and Route Maps A.1 Booster Station and HDD Line A.2 Route from Teesside to the NGC 5/42 Storage Complex A.3 Route from Teesside to the Shell Goldeneye Storage Complex MS986 3 of 87 i-xx-05905

4 Appendix B Concept Design Basis B.1 Generally Applicable Design Basis, including Booster Pumping Station B.2 Route to NGC 5/42 Storage Complex, Specific Basis of Design B.3 Route to Shell Goldeneye Storage Complex, Specific Basis of Design Appendix C Booster Station C.1 15 mtpy Booster Station Concept: C.2 5 mtpy Booster Station Concept Appendix D Route to NGC 5/42 Storage Complex D.1 Route Investigation D.2 Flow Assurance D.3 Mechanical Design D.4 Material Take off List D.5 Commentary on any Major Technical Risks Appendix E Route to Shell Goldeneye CO 2 Storage Complex E.1 Route Investigation E.2 Flow Assurance E.3 Mechanical Design E.4 Material Takeoff E.5 Commentary on any Major Technical Risks MS986 4 of 87 i-xx-05905

5 Glossary of Terms Abbreviation CATS CCS CO 2 CV DECC EU EU-ETS FEED HAS HDD HSE MEL MOD MTOL MTPY NGC NEPIC PBD PFD PIG PLET SAW SSI SSSI TP TVU Description Central Area Transmission System Carbon Capture & Storage Carbon Dioxide Calorific Value Department of Energy & Climate Change European Union European Union-Emissions Trading System Front End Engineering Design Health and Safety Horizontal Direct Drill Health, Safety & Environmental Major Equipment List Ministry of Defence Material Take Off List Million Tonnes Per Year National Grid Carbon North East of England Process Industry Cluster Pale Blue Dot (appointed as Project Coordinator) Process Flow Diagram Pipeline Inspection Gauge Pipeline End Termination Submerged Arc Welded Sahaviriya Steel Industries Sight of Specific Scientific Interest Terminal Point Tees Valley Unlimited MS986 5 of 87 i-xx-05905

6 1 Executive summary This Concept Report deals specifically with Work Package 6 (WP6) of the engineering contract being undertaken by Amec Foster Wheeler for TVU, funded through its City Deal to enable development of an industrial CCS network on Teesside. It summarises the option selection process and sets out the technical basis for two CO 2 Offshore Transportation to Storage infrastructures, such that costs can be estimated and a future FEED study planned and executed by a competent Contractor. The CO 2 Offshore Transportation to Storage Infrastructure is a key component for the Regional Carbon Capture and Storage Infrastructure. The Regional Infrastructure will be most readily delivered through the development of an anchor project, providing a material volume of CO 2 over which the costs of the required transport and storage infrastructure can be amortised. The presence of the Regional infrastructure will act as a magnet for the location and development of other industrial and power facilities needing to implement CCS as part of an overall UK low carbon initiative. For this reason within this study, the offshore transportation to storage infrastructure is designed to handle either 15 mtpy or 5 mtpy of CO 2 and to examine the factors that impact the delivery of such quantities of CO 2 to either the National Grid Carbon Limited (NGC) storage complex referred to as saline aquifer 5/42 (5/42) in the Southern North Sea or to the Shell UK Limited depleted natural gas field called Goldeneye in the Central North Sea. Both potential storage complexes are part of projects that were selected by the Department of Energy and Climate Change through the competitive process for the commercialisation of Carbon Capture and Storage. An optioneering and screening process, including a stakeholder workshop, was undertaken to select the best single route for each proposed storage complex. The design and implementation issues expressed and discussed in the workshop were reduced to the following list of Screening Criteria: (a) Reliable, (b) Maintainable, (c) Inspectable, (d) Simple, (e) Executable, (f) Efficient, and (g) Cost Effective. A scoring system was applied to these criteria to assist in making a relative comparison between alternatives. Based on expectation of relative costs and technical difficulties associated with managing long distance onshore transport of CO 2 for offshore storage, all solutions taken forward were for offshore pipelines. This optioneering phase and down selection process is recorded more fully in Document No X A1. Based on the above analysis, the following two transport routes were selected for the concept development phase. The results of the development phase set pressure requirements; sized booster pumps; determined wall thicknesses, thickness of concrete coatings and stability interventions; and established the lengths and diameters of the proposed pipelines: MS986 6 of 87 i-xx-05905

7 Concept 1: A direct route from Teesside to the NGC 5/42 CO 2 Storage Complex with direct delivery through the subsea isolation valve to the top of platform and PIG receiver to receiving manifold. The concept includes an onshore Booster Station, a 1 km onshore section of pipe and a 154 km offshore section. The Concept 1 pipeline was designed for a 15 mtpy case and a 5 mtpy case with pipeline diameters of 24 inches (600 mm) and 18 inches (450 mm) respectively. Concept 2: A direct route from Teesside to the Shell Goldeneye CO 2 Storage Complex with direct delivery through the subsea isolation valve to the top of platform and PIG receiver to receiving manifold. The concept includes an onshore Booster Station, a 1 km onshore section of pipe and a 433 km offshore section. The Concept 2 pipeline was designed for a 15 mtpy case and a 5 mtpy case with pipeline diameters of 30 inches (760 mm) and 20 inches (500 mm) respectively. During the development phase a high level basis of design was developed. For each of the concepts, a Process Flow Diagram (PFD) showing major streams, a Major Equipment List and a Material Take Off List have been developed. In addition, a commentary on operability and highlighted areas for optimisation has been provided. These provide the basis for the cost estimation work, the business case development and the foundation for a future FEED. As can be seen in the equipment lists, the two 15 mtpy cases differ mainly in the length, wall thickness and diameter of their respective pipelines and the two 5 mtpy cases differ from each other similarly while differing from the 15 mtpy cases in the capacity of the booster pumps and the size of Booster Station pipework and receiving and measuring components. Because the specification for the CO 2 calls for it to be very dry, there is no need for special materials and normal carbon steel is sufficient for pipe work and pipelines. Other components are as supplied by vendors for normal liquid services or CO 2 service. The different concepts considered offer different merits. Final selection will be a function of the outturn expected costs of transportation and storage and the ultimate availability of the storage complex. This work provides the foundation for that decision process, as well as underpinning the basis for the network business case. MS986 7 of 87 i-xx-05905

8 2 Introduction Tees Valley Unlimited is seeking through its City Deal funding to enable the development of an industrial CCS network to support an integrated and carbon efficient industrial hub on Teesside. Key stakeholders in the undertaking include four local industrial emitters (SSI, GrowHow, BOC and Lotte); potential onshore transportation, offshore transportation and storage providers; the local process industry representative body NEPIC; and TVU. The stakeholders, along with the Project Coordinator PBD, are all represented on a Steering Group which oversees the management of the Tees Valley Industrial CCS Project. The overall objective of the Project is to undertake conceptual engineering and prepare preliminary cost estimates with the aim of delivering three interrelated business cases for a network in the area. This Concept Report deals specifically with Work Package 6 (WP6) of the engineering contract being undertaken by Amec Foster Wheeler. It summarises the option selection process and sets out the technical basis for two different CO 2 offshore transportation routes sized for either 5 million tonne per year (mtpy) or 15 mtpy of CO 2 and two different sized booster stations to assure sufficient pressure for the delivery of the CO 2 to the two proposed storage complexes, such that costs can be estimated and a future FEED study can be planned and executed by a competent Contractor. 3 Project Background 3.1 Overarching TVU Project brief The Teesside Process Industry Cluster is one of the largest in the UK covering a diverse sector base of chemicals, petrochemicals, steel-production and energy companies. The cluster employs circa 20,000 people, has a GDP of circa 10bn and exports of circa 4bn per annum. The nature of these industries also makes Teesside one of the most carbon intensive locations in the country. The sector has taken huge strides in improving energy efficiencies in recent years; however, emissions of carbon dioxide are an inherent part of many of the processes and a step change is required to reduce these emissions. If carbon reduction targets are to be met within the timescales envisaged with the current commercially available technology, this can only be realistically achieved by implementing carbon capture and storage at a commercial scale. The process and steel industries on Teesside have reiterated the need and the opportunity for an industrial CCS scheme and have identified a mechanism to approach this through the Tees Valley City Deal. The City Deal is an arrangement between the local area and national Government to transform the economic assets of Teesside, with the development of an industrial CCS network for the area as its priority. The City Deal has provided funding to: complete a pre-feed study for a Tees Valley Industrial CCS network; develop business models for each part of the network; and identify a suitable investment mechanism for industrial CCS support. MS986 8 of 87 i-xx-05905

9 3.2 Purpose of the CO 2 Offshore Transportation to Storage Infrastructure The CO 2 Offshore Transportation to Storage Infrastructure is a key component for the Regional Carbon Capture and Storage Infrastructure. The Regional Infrastructure will be most readily delivered through the development of an anchor project, providing a material volume of CO 2 over which the costs of the required transport and storage infrastructure can be amortised. The presence of the Regional Infrastructure will act as a magnet for the location and development of other industrial and power facilities needing to implement CCS as part of an overall UK low carbon initiative. For this reason within this study, the offshore transportation to storage infrastructure is being designed to handle either 15 mtpy or 5 mtpy of CO 2 and to examine the factors that impact the delivery of such quantities of CO 2 to either the National Grid Carbon Limited (NGC) storage complex referred to as saline aquifer 5/42 (5/42) in the Southern North Sea or to the Shell UK Limited (Shell) depleted natural gas field called Goldeneye in the Central North Sea. Both potential storage complexes are part of projects that were selected by the Department of Energy and Climate Change through the competitive process for the commercialisation of Carbon Capture and Storage. The purpose of this work package is to size the major components of the proposed offshore infrastructure for the two proposed flow regimes and the two proposed routes. These components include the onshore CO 2 Booster Station, the buried onshore dune crossing and sea approach, the offshore CO 2 pipeline and the pipeline riser system to the proposed storage complexes. The study identifies obstacles to be avoided or crossed and provides the basic engineering data for the equipment, the sized components and quantities of material required to enable estimated costs of the high pressure CO 2 offshore transport to storage infrastructure in Work Package 7 (WP7). The WP6 costs combined with the capture costs from WP s 1, 2, 3 & 4; the costs of the onshore CO 2 transport network in WP5 and the storage costs; will enable the Project Co-ordinator (Pale Blue Dot, PBD) to develop the business case for supporting a project which includes an oversized transport and storage system to enable additional industrial emitters in the Teesside area to connect at an economic cost. 3.3 Key Volumes and Parameters The infrastructure proposed under WP6 is working on two flow regimes, 15 mtpy and 5 mtpy, and two delivery locations. A common minimum delivery pressure requirement has been chosen of 100 barg pressure at the top of the storage complex platforms. Both storage complexes require modifications to receive these flow requirements but for comparative purposes, under WP6 a common assumption about the method of delivery of the CO 2 to the top of the respective platform has been used. 3.4 CO 2 Network Requirements An input requirement of the WP6 study work is the provision of a detailed CO 2 specification. This specification is based on the appropriate CO 2 codes and standards, the onshore pipeline network design philosophy and technical codes and standards, and the requirements of the offshore transportation and storage solutions. The specification sets out the CO 2 composition, operating pressure and temperature limits. The composition for this TVU project is defined in Document No DC00-SPE Other inputs include the clear definition of battery limits and the interface requirements of the onshore and MS986 9 of 87 i-xx-05905

10 offshore systems e.g. C&I, metering, other utilities, pigging access etc. In summary, the CO 2 conditions into the onshore transportation network are detailed in Table 3.1 below: Condition Units Minimum Typical Maximum Pressure barg Temperature C Table 3.1 CO 2 conditions at Capture plant battery limits The onshore pipeline network and the SSI capture plant exit Battery Limits shall be the connections to the respective PIG Receivers at the entrance manifold to the onshore booster station. The exit battery Limit to the Offshore Transportation Infrastructure shall be the pipeline exit flange after the Pig Receiver on the Storage Complex injection platform. There shall be no chemical or physical processes between the metering stations of individual capture facilities and the exit Battery Limit for the Offshore Infrastructure that is able to change the composition of the CO 2. MS of 87 i-xx-05905

11 4 Specific Project Objectives The objective of this Work Package 6 is to develop the technical information relating to high pressure offshore transportation of captured CO 2 to the proposed storage complexes: (a) as required for Work Package 7 to develop CAPEX and OPEX estimates, and (b) to provide the technical performance as required by the Project Co-ordinator to develop the business case. The information is to be presented such that it could be used by a competent engineering contractor to plan a FEED study. For this Work Package, there two proposed flow regimes to be considered, 15 mtpy and 5 mtpy. There are also two storage complexes in which to potentially deliver CO 2. Finally, there is a requirement to boost the pressure of the CO 2 from the proposed onshore CO 2 network sufficiently to overcome pressure losses in the offshore pipeline infrastructure to deliver CO 2 at the required delivery pressure for each complex. An optioneering and screening phase was conducted to ensure that the solutions meet the drivers and constraints of the stakeholders, and that the preferred route for each of the storage complexes was selected using an agreed basis for down selection. From this optioneering phase, a preferred Booster Station location was selected, an offshore route to each of the two stores was selected and a common approach to delivering the CO 2 to the top of the storage complex platform was chosen. The specific deliverables for this WP include: A Process Flow Diagram (PFD) showing major streams, A Preliminary Plot Plan of the Booster Station for each flow regime (15 & 5 mtpy), A Major Equipment List (MEL) for process equipment for each flow regime and a Utility Equipment List for support equipment for each flow regime, A Material Take Off list for the pipeline and delivery connections. A commentary on any significant operability issues. MS of 87 i-xx-05905

12 5 Process undertaken 5.1 Overview of screening and optioneering process A modified AMEC Optioneering process was followed for this element of the work programme 1. This required contributions from the Key stakeholders and Pale Blue Dot (PBD), Amec Foster Wheeler and Progressive Energy. Using reference material prepared by the team, a workshop was undertaken to (a) Review and understand the potential transport route options onshore and offshore, (b) Understand the constraints and drivers associated with the two storage complexes under review and identify necessary information required to assist further analysis, (c) generate alternative routes if available, and (d) use the constraints and drivers to undertake a coarse screening exercise. This provided a very short list of route options and enabled the group assembled to agree down selection. Information requests were made of each of the storage complex development teams to ascertain the best means of connecting to each of the storage complexes. Provisional work was completed on flow assurance and pipeline sizes to further assist in analysis of the design requirements of the systems. The output of this process was a short list of a single route to each of the two storage complexes and a common means of delivering CO 2 to the top of the respective storage platforms. This optioneering phase and down selection process is recorded more fully in Document No X A Overview of Concept development process Following completion of the Optioneering and Screening activities a high level Basis of Design for the selected Concepts was produced. This was used to develop the proposed concept designs, based on further flow assurance modelling and analysis. The output from this is a Process Flow Diagram and an analysis of the energy requirements for both transport routes and both flow regimes. This has been used to inform the production of the preliminary plot plan as well as provide a Major Equipment List and a Utility Equipment List suitable for cost estimating purposes. Finally, a Material Take Off List was prepared covering the overall pipeline lengths, the crossings, cathodic protection and the termination scope of supply. The WP6 quantities and equipment lists will be input into WP7 whole project cost estimating process as part of development and delivery of the Business Case by the Project Co-ordinator, PBD DC00-PHL-001 Rev P1: TVU CCS Pre-FEED Optioneering Philosophy MS of 87 i-xx-05905

13 6 Summary of selected options for concept development and costing The purpose of the initial element of WP6 of the Technical Work Contract was to identify the most appropriate routes to each of the two proposed storage complexes under the UK Government CCS Commercialisation Programme and in a collaborative workshop, select one route for each storage complex. The selected routes provided the basis for the subsequent concept engineering development reported upon in this Report. The storage complexes are: (a) The National Grid store known as 5/42 associated with the White Rose CCS Project in West Yorkshire, and (b) The Shell Goldeneye store associated with the Peterhead CCS Project in Scotland. The location and broad concepts for the routes are shown indicatively on the map below (Figure 6.1.1) Figure 6.1.1: Map showing the possible destinations for the Teesside Industrial CO 2 Three broad options were considered for the pipeline to the National Grid store known as 5/42: 1. New build offshore pipeline to a location onshore in Yorkshire, where the CO 2 would be comingled with the White Rose CO 2 and pumped offshore, 2. New build pipeline to a new T-piece in the offshore section of the National Grid pipeline, and 3. New build pipeline to the National Grid pipeline to the 5/42 store offshore. MS of 87 i-xx-05905

14 Three routes were reviewed from Teesside to the Shell Goldeneye Storage Complex which included: 1. All onshore to St Fergus and then on to the Goldeneye store, 2. Entirely offshore from Teesside to the Goldeneye store, and 3. Offshore from Teesside to tie in onshore in the Central Belt. The collaborative workshop was attended by Pale Blue Dot, Industrial partners and members of the Progressive and AMEC teams. The design and implementation concerns expressed and discussed in the Workshop were reduced to the following list of Screening Criteria: (a) Reliable, (b) Maintainable, (c) Inspectable, (d) Simple, (e) Executable, (f) Efficient, and (g) Cost Effective. A simple scoring system was applied to these criteria to assist in making a relative comparison between alternatives. Based on expectation of relative costs and technical difficulties associated with managing long distance onshore transport of CO 2 for offshore storage, all solutions taken forward were for offshore pipelines. This optioneering phase and down selection process is recorded more fully in Document No X A1. Based on the above analysis, the following two transport routes were selected for the concept development phase: Concept 1: A direct route from Teesside to the NGC 5/42 CO 2 Storage Complex with direct delivery through the subsea isolation valve to the top of platform and PIG receiver to receiving manifold. The pipeline would be designed for both a 15 mtpy case and a 5 mtpy case. Concept 2: A direct route from Teesside to the Shell Goldeneye CO 2 Storage Complex with direct delivery through the subsea isolation valve to the top of platform and PIG receiver to receiving manifold. The pipeline would be designed for both a 15 mtpy case and a 5 mtpy case. The choice of delivery point was made to be identical for comparison purposes, as neither the existing Goldeneye facility nor the proposed NGC 5/42 facility would be able to receive the two levels of flows contemplated in this study without modifications to plans for the existing facilities and fields and it may be necessary to send CO 2 to alternative geological structures in close proximity to these two complexes in order to have sufficient storage capacity for multiple projects over time. This will require a significant level of coordination to best utilise the infrastructure the UK government hopes to see developed under a wider CCS programme. MS of 87 i-xx-05905

15 7 Concept 1: Route to the NGC Storage Complex 5/ Concept definition This concept is based on the transport of CO 2 to the closest storage complex within the DECC CCS Commercialisation Programme. The complete offshore transport infrastructure includes a Booster Station, a 1 km section of Horizontally Directionally Drilled onshore pipe, a 154 km section of offshore pipe and a Termination at the top of the NGC 5/42 Storage Complex Platform The overall offshore infrastructure and route maps are shown in Appendix A, with concept specific elements in A.2. The overall Basis of Design is found in Appendix B, with concept specific elements in B.2. The Booster station is described below. Detailed information relating to the Concept 1 route, including the route investigation, flow assurance, mechanical design, Material Take off List and commentary on any major technical risks is found in Appendix D. In summary, the route crosses three natural gas pipelines and four communication cables and three proposed electrical export cables form the offshore Dogger Bank Wind Farm. The route also avoids crossing an MOD submarine testing area and closes in on the storage complex through an area of sand waves. Thirty-five kilometres of the proposed pipeline from the shore approach outward will be trenched while the remainder of the line will be directly laid onto the sea bed. The pipeline will be continuously laid off the back of a pipeline lay barge moving at approximately 4,000 metres per day. The lay barge will be supported by tug boats, supply barges, a diver support vessel, a trenching vessel & plough and spotter vessels from the local fishing fleet. The Process flow diagram, Preliminary Plot Plan and Major Equipment List for the two Booster Station designs of 15 mtpy and 5 mtpy are found in Appendix C. The concept process elements for the Booster Station are described briefly below CO 2 PIG Receiver (Unit A-1001) A PIG receiver is required for pigging the pipeline from the other onshore capture plants to the inlet manifold to the booster station. This requires the PIG receiver and full-bore valves (600 mm and 400 mm respectively), with associated vent pipework to the Booster Station vent stack and an A-frame for PIG handling CO 2 PIG Receiver (Unit A-1002) A PIG receiver is required for pigging the pipeline from the SSI capture plant to the inlet manifold to the booster station. This requires the PIG receiver and full-bore 400 mm valves, with associated vent pipework to the Booster Station vent stack and an A-frame for PIG handling CO 2 Monitoring & Metering (Unit A-1003) The metering station will measure CO 2 temperature and pressure, the composition and the mass or volumetric flow. This is the Fiscal Meter for the network and the accuracy of the metering shall be MS of 87 i-xx-05905

16 such that it meets the requirements for allocation measurements relating to the credits for nonemission of the CO 2 to air, and any other commercial or contractual requirements CO 2 Booster Pumps (Units P-1001 A/B/C) The pressure of the CO 2 from the Onshore Network will be boosted from 100 barg to approximately 160 barg. Three 50% pumps will provide 99% availability. No further cooling of the CO 2 is required due to the cooling effect of the buried and trenched portion of the offshore pipeline CO 2 PIG Launcher (Unit A-1004) A PIG launcher is required for pigging the pipeline from the Booster Station to the Offshore Storage Complex. This requires the launcher and full-bore valves (610 mm and 457 mm respectively), with associated vent pipework to the Booster Station vent stack and an A-frame for pig handling CO 2 Vent Stack (Unit A-1005) A Vent Stack is proposed to vent all CO 2 evacuated from booster station internal pipelines during maintenance operations and if required to vent CO 2 from other parts of the system if pressure builds up behind two sets of closed valves. There is no anticipation that the main offshore pipeline system will be evacuated once commissioned until decommissioned. The Vent stack is 20 meters in height Backup Diesel Generator (Unit E-1003) To maintain the level of availability required, a 4 MW backup diesel generator has been assumed to supply 100% of the power needs for the 5 mtpy case. This is also sufficient for initial operation of the 15 mtpy case Buildings (Unit E-1004) The Booster Station and Offshore Pipeline is operated and controlled from a remotely located Control Centre. An onsite control room is proposed for onsite inspection and operation during maintenance periods. The control block will also house the Switch Gear and Motor Control Centre for the Booster Station. This is a simple clad steel structures or block structure. Additional small utility equipment is also required to provide compressed air, nitrogen, service water, potable water and diesel fuel. This is detailed further in Appendix C MS of 87 i-xx-05905

17 7.2 Summary of key engineering performance parameters Key technical parameters for business evaluation purposes for WP6 Concept 1, 15 mtpy case are as follows: Export CO 2 Units Value Comments Flowrate kg/hr 1,712,000 Temperature C 35 Inlet Pressure barg 100 See Appendix B.1.1 Outlet Pressure barg 160 Annual Volume Tonnes 15,000,000 Based on overall system availability Utilities Electrical Load MWe Booster Station Pumps & Utility loads Service and Potable Water from onsite Water kg/hr minimal storage. Performance System Availability % 99% See Section 7.3 Table 7-1 Key Engineering Parameters for Concept 1 15 mtpy case Key technical parameters for business evaluation purposes for WP6 Concept 1, 5 mtpy case are as follows: Export CO 2 Units Value Comments Flowrate kg/hr 570,000 Temperature C 35 Inlet Pressure barg 100 See Appendix B.1.1 Outlet Pressure barg 160 Annual Volume tonnes 5,000,000 Based on overall system availability Utilities Electrical Load MWe Booster Station Pumps & Utility loads Service and Potable Water from onsite Water kg/hr minimal storage tanks. Performance System Availability % 99% See Section 7.3 Table 7-2 Key Engineering Parameters for Concept 1 5 mtpy case All pipeline materials proposed are Material Grade X65 or DNV SAW1450F, typical grades of carbon steel. All pipelines to have an exterior High Density Three Layer Polyethylene (HD-3LPE) coating applied for corrosion protection (nominally 3mm thick). No internal coating should be applied as this will react with the CO 2 and flake off over time. For protection and to maintain depth and stability when pipeline is installed and empty, the offshore pipelines will be trenched and concrete coated with a coating of 75 mm in close proximity to shore in less than 50 metres of water and thereafter directly laid on seabed and concrete coated with a coating of 50 mm. Table 7 3 indicates length and wall thicknesses for proposed Concept 1 pipelines. MS of 87 i-xx-05905

18 Annual Flow 15 mtpy 5 mtpy Pipe Diameter (inches / mm) 24 / / 457 Pipeline Wall Thicknesses by type / length HDD Onshore (mm) 1 km Offshore Pipeline (mm) 154 km Table 7 3 Concept 1 Pipeline Wall Thicknesses for 15 & 5 mtpy cases 7.3 High level operability review System Availability For the Booster Station, at this concept stage, 3 x 50% pumps are proposed to provide 99% availability for the Transport Infrastructure. A backup Diesel Generator capable of supplying the power requirement is also included. During FEED, a RAM analysis should determine if another Diesel Generator is required given that if the power is cut to the region, the capture plant outputs may be impacted. This proposed diesel generator is to supply power for continuing flow or during a controlled shutdown. Other Utility equipment within the Booster Station is configured with sufficient redundancy to maintain 99% availability. However, during FEED a full RAM analysis should be undertaken to confirm this, and optimise equipment design and specifications accordingly Reference Plants Booster Stations of this type exist all along the extensive 5,900 km CO 2 pipeline network in the US and Canada with over 10 years of operation, using the Flowserve Pumps proposed here. These are modified Centrifugal Pumps with nitrogen packed mechanical seals to isolate the CO 2 from the external elastomeric seals Operational and Optimisation Commentary The following briefly summarises operational and optimisation areas for review and optimisation during FEED. It is assumed that the CO 2 network can be commissioned utilising CO 2 from GrowHow. This substantially reduces operational risk. Teesside is unique in the UK in having this asset. This can be used to purge and fill lines back to individual capture plants Capture would only be brought on stream once the capture plant was operating under stable conditions and the CO 2 lines are filled and ready to take. In the event of failure to-take CO 2, capture plants will be bypassed; with the flue gas emitted directly using the normal flue stack. With regard to the wider CCS infrastructure, flue stacks could provide an MS of 87 i-xx-05905

19 important vent for the CO 2 lines if required, providing the necessary buoyancy for dispersion. This should be considered during detailed system design. However, normal practice in the event of interrupted supply of CO 2 is to leave the remaining CO 2 pipelines full at all times and monitor pressure in both the onshore and offshore pipelines and monitor pressures to make sure they do not build up between two closed isolation valves. A vent stack system at the Booster Station is also available to vent CO 2 especially for segments of piping within the Booster Station emptied during any maintenance on one or more pumps. If there are multiple suppliers of CO 2, there should always be a supply of CO 2 entering the pipeline so pressure can easily be maintained above the bubble point of the mixture. The likelihood of this should be evaluated during FEED. MS of 87 i-xx-05905

20 8 Concept 2: Route to Shell Goldeneye Storage Complex 8.1 Concept definition This concept is based on the transport of CO 2 to the closest storage complex within the DECC CCS Commercialisation Programme. The complete offshore transport infrastructure includes a Booster Station, a 1 km section of Horizontally Directionally Drilled onshore pipe, a 433 km section of offshore pipe and a Termination at the top of the Shell Goldeneye Storage Complex Platform. The overall offshore infrastructure and route maps are shown in Appendix A, with concept specific elements in A.3. The overall Basis of Design is found in Appendix B, with concept specific elements in B.3. The Booster station is described below. Detailed information relating to the Concept 2 route, including the route investigation, flow assurance, mechanical design, Material Take off List and commentary on any major technical risks is found in Appendix E. In summary the route crosses two oil pipelines and two natural gas pipelines but does not cross any active communication cables. Twenty kilometres of the proposed pipeline from the shore approach outward will be trenched while the remainder of the line will be directly laid onto the sea bed. The Pipeline will be continuously laid off the back of a pipeline lay barge moving at approximately 4,000 metres per day. The lay barge will be supported by tug boats, supply barges, a diver support vessel, a trenching vessel & plough and spotter vessels from the local fishing fleet. The Process flow diagram, Preliminary Plot Plan and Major Equipment List for the two Booster Station designs of 15 mtpy and 5 mtpy are found in Appendix C. The concept process elements for the Booster Station are described briefly below CO 2 PIG Receiver (Unit A-1001) A PIG receiver is required for pigging the pipeline from the other onshore capture plants to the inlet manifold to the booster station. This requires the PIG receiver and full-bore valves (600 mm and 400 mm respectively), with associated vent pipework to the Booster Station vent stack and an A-frame for PIG handling CO 2 PIG Receiver (Unit A-1002) A PIG receiver is required for pigging the pipeline from the SSI capture plant to the inlet manifold to the booster station. This requires the PIG receiver and full-bore 400 mm valves, with associated vent pipework to the Booster Station vent stack and an A-frame for PIG handling CO 2 Monitoring/metering (Unit A-1003) The metering station will measure CO 2 temperature and pressure, the composition and the mass or volumetric flow. This is the Fiscal Meter for the network and the accuracy of the metering shall be such that it meets the requirements for allocation measurements relating to the credits for nonemission of the CO 2 to air, and any other commercial or contractual requirements. MS of 87 i-xx-05905

21 8.1.4 CO 2 Booster Pumps (Units P-1001 A/B/C) The pressure of the CO 2 from the Onshore Network will be boosted from 100 barg to approximately 160 barg. Three 50% pumps will provide 99% availability. No further cooling of the CO 2 is required due to the cooling effect of the buried and trenched portion of the offshore pipeline CO 2 PIG Launcher (Unit A-1004) A PIG launcher is required for pigging the pipeline from the Booster Station to the Offshore Storage Complex. This requires the launcher and full-bore valves (760 mm and 500 mm respectively), with associated vent pipework to the Booster Station vent stack and an A-frame for pig handling CO 2 Vent Stack (Unit A-1005) A Vent Stack is proposed to vent all CO 2 evacuated from booster station internal pipelines during maintenance operations and if required to vent CO 2 from other parts of the system if pressure builds up behind two sets of closed valves. There is no anticipation that the main offshore pipeline system will be evacuated once commissioned until decommissioned. The Vent stack is 20 meters in height Backup Diesel Generator (Unit E-1003) To maintain the level of availability required, a 4 MW backup diesel generator has been assumed to supply 100% of the power needs for the 5 mtpy case. This is also sufficient for initial operation of the 15 mtpy case Buildings (Unit E-1004) The Booster Station and Offshore Pipeline is operated and controlled from a remotely located Control Centre. An onsite control room is proposed for onsite inspection and operation during maintenance periods. The control block will also house the Switch Gear and Motor Control Centre for the Booster Station. This is a simple clad steel structures or block structure. Additional small utility equipment is also required to provide compressed air, nitrogen, service water, potable water and diesel fuel. This is detailed further in Appendix C MS of 87 i-xx-05905

22 8.2 Summary of key engineering performance parameters Key technical parameters for business evaluation purposes for WP6 Concept 2, 15 mtpy case are as follows: Export CO 2 Units Value Comments Flowrate kg/hr 1,712,000 Temperature C 35 Inlet Pressure barg 100 See Appendix B.1.1 Outlet Pressure barg 160 Annual Volume tonnes 15,000,000 Based on overall system availability Utilities Electrical Load MWe Booster Station Pumps & Utility loads Service and Potable Water from onsite Water kg/hr minimal storage. Performance System Availability % 99% See Section 8.3 Table 8-1 Key Engineering Parameters for Concept 2 15 mtpy case Key technical parameters for business evaluation purposes for WP6 Concept 2, 5 mtpy case are as follows: Export CO 2 Units Value Comments Flowrate kg/hr 570,000 Temperature C 35 Inlet Pressure barg 100 See Appendix B.1.1 Outlet Pressure barg 160 Annual Volume tonnes 5,000,000 Based on overall system availability Utilities Electrical Load MWe Booster Station Pumps & Utility loads Service and Potable Water from on site Water kg/hr minimal storage tanks. Performance System Availability % 99% See Section 8.3 Table 8-2 Key Engineering Parameters for Concept 2 5 mtpy case All pipeline materials proposed are Material Grade X65 or DNV SAW1450F, typical grades of carbon steel. All pipelines to have an exterior High Density Three Layer Polyethylene (HD-3LPE) coating applied for corrosion protection (nominally 3mm thick). No internal coating should be applied as this will react with the CO 2 and flake off over time. The offshore pipelines will be concrete coated with a coating of 75 mm in close proximity to shore in less than 50 metres of water and 50 mm thereafter in order to maintain depth and stability when pipeline is installed and empty. Table 8 3 indicates length and wall thicknesses for proposed Concept 2 pipelines. MS of 87 i-xx-05905

23 Annual Flow 15 mtpy 5 mtpy Pipe Diameter (inches / mm) / length 30 / / 508 Pipeline Wall Thicknesses by type / length HDD Onshore (mm) 1 km Offshore Pipeline (mm) 433 km High level operability review System Availability Table 8 3 Concept 2 Pipeline Wall Thicknesses for 15 & 5 mtpy cases For the Booster Station, at this concept stage, 3 x 50% pumps are proposed to provide 99% availability for the Transport Infrastructure. A backup Diesel Generator capable of supplying the power requirement is also included. During FEED, a RAM analysis should determine if another Diesel Generator is required given that if the power is cut to the region, the capture plant outputs may be impacted. This proposed diesel generator is to supply power for continuing flow or during a controlled shutdown. Other Utility equipment within the Booster Station is configured with sufficient redundancy to maintain 99% availability. However, during FEED a full RAM analysis should be undertaken to confirm this, and optimise equipment design and specifications accordingly Reference Plants Booster Stations of this type exist all along the extensive 5,900 km CO 2 pipeline network in the US and Canada with over 10 years of operation, using the Flowserve Pumps proposed here. These are modified Centrifugal Pumps with nitrogen packed mechanical seals to isolate the CO 2 from the external elastomeric seals Operational and Optimisation Commentary The following briefly summarises operational and optimisation areas for review and optimisation during FEED. It is assumed that the CO 2 network can be commissioned utilising CO 2 from GrowHow. This substantially reduces operational risk. Teesside is unique in the UK in having this asset. This can be used to purge and fill lines back to individual capture plants Capture would only be brought on stream once the capture plant was operating under stable conditions and the CO 2 lines are filled and ready to take. In the event of failure to-take CO 2, capture plants will be bypassed; with the flue gas emitted directly using the normal flue stack. This is an advantage of an end of pipe solution. With regard to the wider CCS infrastructure, flue stacks could provide an important vent for the CO 2 lines if required, providing the necessary buoyancy for dispersion. This should be considered during detailed system design. However, normal practice in the event of interrupted supply of CO 2 is to leave the remaining CO 2 pipelines full at all times and monitor pressure in both the onshore and offshore pipelines and MS of 87 i-xx-05905

24 monitor pressures to make sure they do not build up between two closed isolation valves. A vent stack system at the Booster Station is also available to vent CO 2 especially for segments of piping within the Booster Station emptied during any maintenance on one or more pumps. If there are multiple suppliers of CO 2, there should always be a supply of CO 2 entering the pipeline so pressure can easily be maintained above the bubble point of the mixture. The likelihood of this should be evaluated during FEED. MS of 87 i-xx-05905

25 9 Conclusions The objective of this Work Package 6 is to develop the technical and quantitative information relating to the two proposed offshore pipelines each at two different flows and the booster station design for those two different flows and different pressures. This information is then provided: (a) as required for Work Package 7 to develop CAPEX and OPEX estimates, and (b) to provide the technical performance as required by the Project Co-ordinator to develop the business case. An optioneering and screening process was undertaken to ensure that the full range of transport options were considered, and to provide the basis for down selection. This included a workshop with key stakeholders to review the alternatives and generate drivers and constraints and to provide an agreed basis for down selection. One route was selected for each potential storage complex and that route was evaluated for two flow regimes. The two concepts which were further developed are: Concept1: A direct route from Teesside to the NGC 5/42 CO 2 Storage Complex with direct delivery through the subsea isolation valve to the top of platform and PIG receiver to receiving manifold. The concept includes an onshore Booster Station, a 1 km onshore section of pipe and a 154 km offshore section. The Concept 1 pipeline was designed for a 15 mtpy case and a 5 mtpy case with pipeline diameters of 24 inches (600 mm) and 18 inches (450 mm) respectively. Concept 2: A direct route from Teesside to the Shell Goldeneye CO 2 Storage Complex with direct delivery through the subsea isolation valve to the top of platform and PIG receiver to receiving manifold. The concept includes an onshore Booster Station, a 1 km onshore section of pipe and a 433 km offshore section. The Concept 2 pipeline was designed for a 15 mtpy case and a 5 mtpy case with pipeline diameters of 30 inches (760 mm) and 20 inches (500 mm) respectively. During the development phase a high level basis of design was developed. For each of the concepts, A Process Flow Diagram (PFD) was developed for the Booster Station along with a site layout drawing for the 15 mtpy and the 5 mtpy cases. Additionally a Major Equipment List and a Utility Equipment List have been developed. Finally, a commentary on operability and highlighted areas for optimisation has been provided. These documents provide the basis for the cost estimation work, the business case development and the foundation for a future FEED and can be found in the Appendices. Other key points and conclusions from the work represented in the Appendices include: It is viable to transport dense phase CO 2 to either destination using proven equipment, technologies, materials and techniques and account for such transport through measuring and monitoring systems. MS of 87 i-xx-05905

26 Certain elastomeric materials used to seal pump shafts are to be avoided because they are miscible to CO 2 which may lead to seal failure due to explosive decompression when pressure is withdrawn from the seal. The proposed Offshore Transport Infrastructure is designed for a high level of uptime, 99%. The proposed Booster Station is common to both offshore routes and is proposed to be located on isolated portion of TATA land, i.e. outside the control of current participants. All pipelines to have an exterior High Density Three Layer Polyethylene (HD-3LPE) coating applied for corrosion protection (nominally 3mm thick). No internal coating should be applied as this will react with the CO 2 and flake off over time. The offshore pipelines will be concrete coated with a coating of 75 mm in close proximity to shore in less than 50 metres of water and 50 mm thereafter in order to protect and maintain depth and stability when pipeline is installed and empty. During FEED optimisation, the costs for the final pipeline may be reduced if actual minimum wall thicknesses were used instead of nearest standard pipe wall thicknesses for the 15 mtpy case in Concept 1 or the 5 mtpy case in Concept 2. A 16 inch line could be used for the 5 mtpy case to the NGC 5/42 complex but it would require trenching along the full route and 16 inch seamless pipe can be nearly as costly as an 18 inch standard schedule SAW pipe. The major technical risks associated with the installation and operation of the offshore infrastructure are: o o Maintaining the CO2 in the dense phase. Accomplished through simple pressure management thus avoiding two phase flow and its potential consequences of liquid hammer, drop out of dissolved water and pump cavitation. Protecting the pipeline and structures from interactions from ships anchors and fishing gear. Accomplished by sufficiently burying pipeline on the shore approach in less than 50 metres of water and concrete coating of all fabricated offshore pipe. Likewise, providing rock dump protection over all pipeline and cable crossings and any subsea manifold structures if added to the design in the future to accommodate other delivery approaches or pipeline connections. In summary, this work has delineated two routes for two different flows and sized the respective pipeline diameters and wall thicknesses to match with the booster station capabilities. The different concepts considered offer different merits. Final selection will be a function of the outturn expected cost of installation, storage costs and whether the storage complex or one similar in the area will be available to receive the proposed volumes of CO 2. This work provides the foundation for that decision process, as well as underpinning the basis for the network business case. MS of 87 i-xx-05905

27 Appendix A Overall Offshore Infrastructure and Route Maps A.1 Booster Station and HDD Line The first major component of the Offshore Infrastructure is the on shore CO 2 Booster Station. This facility receives 100 barg CO 2 from the SSI Capture Plant by way of a 400 mm pipeline and from the Onshore CO 2 Network from either a 400 mm or a 600 mm pipeline based on the respective capacities for the system of either 5 mtpy or 15 mtpy of CO 2. The Booster Station increases the pressure of the received CO 2 to the required pressure to overcome the pressure losses in the pipelines to deliver CO 2 to the top of the respective storage complex s off shore platform at a pressure of 100 barg. The Booster Station is proposed to be located on TATA Industries owned land just east of the SSI Hot Metal Line just south of Gare Road as shown in Figure A.1.1. The 100 barg pipeline from the SSI Steel Works will cross the Hot Metal Line and will terminate in the eastern corner of the Booster Station. The 100 barg Onshore CO 2 Network will come from the South East and also will terminate in the eastern corner of the Booster Station. The high pressure discharge line from the Booster Station will leave the booster station and be joined to an approximately 1 km subsurface horizontal directionally drilled (HDD) pipeline directed underneath the Breagh and CATS natural gas pipelines almost dew northward to a location in the centre of the beach beyond the sand dune area. From here the HDD pipeline will be joined to the offshore line that will be pretrenched and floated onto the shore for connection. The HDD line is the second major component of the Offshore Infrastructure and is depicted in Figure A.1.2 below alongside an alternative open trench arrangement. This alternative arrangement was not chosen because it is less likely to receive approval from the owners of the existing pipelines, Breagh and CATS Natural Gas Lines) and the statutory consultative parties required to review all planning applications for disturbance of wildlife in this Sight of Specific Scientific Interest (SSSI). However, previous discussions with authorities and consultative parties have indicated a favourable view toward an HDD approach for this section of pipeline. MS of 87 i-xx-05905

28 W SSI CCS Hot Metal Line Booster Station N S E Figure A.1.1 Booster Station Location MS of 87 i-xx-05905

29 Figure A.1.2 Route of Onshore HDD MS of 87 i-xx-05905

30 A.2 Route from Teesside to the NGC 5/42 Storage Complex The proposed route from Teesside to the NGC Storage complex is shown in Figure A.2.1. The proposed route is approximately 154 km long crossing three pipelines and eight cables along the way as shown in Table A.2.1. The route is further complicated by the presence of a submarine exercise area where submarines practice, sitting on the subsea surface. While the proposed pipeline is trenched for the first 35 km of length, this area requires either the avoidance of the area or the further trenching of the length of the crossed submarine exercise area. This study assumes a slight deviation to avoid the area altogether as the crossing of the area also contains three of the communication cables along the route which require above subsea surface crossings and would create a major structure within the area. This can be avoided by the proposed route north of the Submarine Area. Crossing No. Type of Crossing Existing Pipe/Cable 1 CATS 36in Gas 2 Pipeline BREAGH 20in Gas 3 LANGELED 44in GAS 4 TEESSIDE NORTH EXPORT 5 CANTAT 3 F4 6 PANGEA North UK/DMK (Out of use) 7 TEESSIDE SOUTH EXPORT Cable UK-Denmark 4 8 (Out of use) 9 VSNL North Europe e 10 UK-Germany 6 (Conflicting Info on use) 11 CREYKE BECK EXPORT Table A.2.1 Crossings Along Proposed Pipeline Route to NGC 5/42 MS of 87 i-xx-05905

31 Figure A.2.1 Overall Route from Teesside to the NGC 5/42 Storage Complex Figure A.2.2. shows a more detailed view of the Shore Approach for the proposed pipeline to 5/42. The pipeline can be seen to be routed to cross the CATS Natural Gas Line, the new Breagh Natural Gas Line, two communication cables and the two approaching electrical export cables from the proposed Dogger Bank wind farm. Agreements will have to be obtained from each of these parties for crossing their pipelines or cables. Past practices indicate that they typically require crossings to be made as close to a 90 degree approach and not less than 60 degrees. The proposed route has been able to achieve a near 90 degree approach for each of these crossings. Further discussion of the overall route and pipeline design can be found in Appendix D. MS of 87 i-xx-05905

32 Figure A.2.2 Shore Approach for Route from Teesside to the NGC 5/42 Storage Complex Figures A.2.3 to A.2.7 show the remaining route to the NGC 5/42 Storage Complex. Points of interest are the location of the Submarine Exercise Area, the communication cable crossings, the crossing for the Langeled natural gas line and the Creyke Beck Export Transmission Line from Dogger Bank. Each of these crossing needed to approach a crossing angle of 90 degrees and no less than 60 degrees. Further trenching may be required through the sand wave region close to the 5/42 Storage Complex but this and direction through the sand wave region will need to be assessed during the proposed FEED period. MS of 87 i-xx-05905

33 Figure A.2.3 Proposed CO 2 line paralleling the Breagh natural gas pipeline MS of 87 i-xx-05905

34 Figure A.2.4 Proposed CO 2 line paralleling the Breagh natural gas pipeline north of the Submarine Exercise Area MS of 87 i-xx-05905

35 Figure A.2.5 Proposed CO 2 line turning south after Submarine Exercise Area, crossing two communication cables and setting up for two further crossings to the south. MS of 87 i-xx-05905

36 Figure A.2.6 Proposed CO 2 line turning southwest to cross Langeled natural gas pipeline and the Creyke Beck Export Transmission Line from the Dogger Bank wind farm before entering the sand wave region in parallel with the wave formation. MS of 87 i-xx-05905

37 Figure A.2.7 North-westerly Approach Route of Proposed CO 2 line from Teesside to the NGC CO 2 Storage Complex. MS of 87 i-xx-05905

38 A.3 Route from Teesside to the Shell Goldeneye Storage Complex The proposed route from Teesside to the Shell Goldeneye Storage complex is shown in Figure A.2.1. The proposed route is approximately 433 km long crossing four pipelines as shown in Table A.3.1 and three disused communication cables that should be cut and removed from area of pipeline. No active communication cables are along the route. The proposed pipeline is trenched for the first 20 km of length. Further discussion of the proposed route to the Shell Goldeneye Storage Complex is covered in Appendix E. Crossing No. Type of Crossing Existing Pipe/Cable 1 EKOFISK 34in Oil 2 FULMER to ST FERGUS 20in Gas 3 Pipeline FORTIES to CRUDEN BAY 36in Oil 4 BRITANNIA to ST FERGUS 27in Gas Table A.3.1 Crossings Along Proposed Pipeline Route to Goldeneye MS of 87 i-xx-05905

39 Figure A.3.1 Route from Teesside to the Shell Goldeneye Storage Complex Figure A.3.1 and A.3.2 also show a closer view of the Shore Approach for the proposed pipeline to Goldeneye. The proposed pipeline can be seen to be routed to nearly parallel the CATS Natural Gas Line as it approaches the crossing of the Ekofisk Oil Pipeline. This portion of the line is also the only portion that needs to be trenched along the first 20 km. From the crossing of the Ekofisk oil pipeline, the CO 2 route goes almost directly north to the Goldeneye Platform. No further crossings are required until the pipeline is in much closer proximity to the Goldeneye Storage Complex. The only matter of interest is that the pipeline route crosses a very extensive MOD surface firing range and this will require coordination during the time of laying the pipeline with respect to the lay barge and support vessels. The final three of 15 route maps show the other three pipeline crossings and show the southerly approach to the Goldeneye Storage Complex. The southerly approach is clear of any existing pipelines; however, access to the platform needs further agreement with Shell. This study assumes a direct connection through a riser onto the platform for comparison purposes with the similar approach on the NGC 5/42 Platform. MS of 87 i-xx-05905

40 Figure A.3.2 Shore Approach for Route from Teesside to the Shell Goldeneye Storage Complex MS of 87 i-xx-05905

41 Figure A.3.3 Route from Teesside to the Shell Goldeneye Storage Complex showing crossing of Fulmar to St Fergus natural gas pipeline MS of 87 i-xx-05905

42 Figure A.3.4 Route from Teesside to the Shell Goldeneye Storage Complex showing crossing of the Forties to Cruden Bay oil pipeline and the Britannia to St Fergus natural gas pipeline MS of 87 i-xx-05905

43 Figure A.3.5 Southerly Approach Route from Teesside to the Shell Goldeneye Storage Complex MS of 87 i-xx-05905

44 Appendix B Concept Design Basis B.1 Generally Applicable Design Basis, including Booster Pumping Station B.1.1 CO 2 Delivery Specification The pressure of the export CO 2 has been agreed as 100barg at the Booster station manifold Battery Limit on the basis of infrastructure optimisation carried out as part of WP5. The temperature of the CO 2 has been specified in WP5 within the range >5 C and <40 C at the Battery Limit. The composition for this TVU project is defined in Document No DC00-SPE B.1.2 CO 2 Terminal Point Definition The inlet battery limit to the Booster Station shall be at the inlet manifold to the booster station, downstream of the pipeline from the SSI capture plant and the rest of the onshore CO 2 network, compression and CO 2 allocation metering & monitoring system. The isolation valves at the inlet battery limit is within the Booster station scope of supply. PIG Receivers from each of the two import lines will be part of the scope for the Booster Station. Fiscal Metering will also be supplied upstream of the booster pumps. B.1.3 Climatic Data Ambient temperature conditions for Redcar over the past ten years are: B.1.4 Max temp: 32.2 C Min temp: C Average Max: 16.9 C Average Min: 4.9 C Design Life The design life of the main offshore transportation infrastructure to storage will be based on a 40 year life expectancy. However, the onshore Booster Station will be designed for a minimum life expectancy of 25 years with the ability to easily replace or upgrade such onshore facilities. B.1.5 Availability The capture and compression along with associated systems shall be designed to have an annual average availability of at least 99%. It shall be assumed that the overall sparing policy and auxiliary plant redundancy design will be commensurate with this level of performance. A RAM analysis should form part of a follow on FEED Process for optimisation. MS of 87 i-xx-05905

45 B.1.6 Electrical Systems High voltage electrical connections are available from the Regional Distribution Network substation on Gare Road to the East of the Booster Station at 11kV. The main 11kV load connections, switchgear and protected systems shall be housed in a local control block at the Booster Station. An outdoor 11kV/6.6kV outdoor transformer and associated switchgear and protection systems shall be provided for main pump operation and a 6.6kV/400V outdoor transformer and associated switchgear and protection systems shall be provided for the low voltage TP&N drives and auxiliary systems, with 230V for single phase power supplies. B.1.7 Civils A full ground investigation will be undertaken on the nominated site to provide geo-technical and geo-environmental information to assist in determining site preparation and foundation design and conditions for the Horizontal Directional Drill (HDD) under dunes to the beach. Particular attention will be paid to the foundations in the vicinity of the booster pumps because of weight and vibration considerations. No geotechnical surveys or soils investigations are available at this stage. Concrete paving is assumed to be required for personnel and maintenance access only, with the remaining area covered by gravel to restrict vegetation growth. Permanent hard standing is not assumed to be required for construction access, and or craneage. If required, this shall be handled by temporary plating as part of the EPC contract. The only building required is a local control room for local monitoring to also house the switch gear and motor control centre. The booster pumps, PIG receivers, PIG launcher and metering facilities will be outdoor installations. The Booster Station will be remotely controlled by the operator of the offshore transportation infrastructure from a central control facility. B.1.8 Piping Pipeline sizes will be selected to minimise pressure drop through the length of the transport pipelines and materials will comply with relevant codes and standards and analysis applicable to operating conditions and transported medium. It is expected all pipelines within the confines of the Booster Station will be run above ground on new pipe racks. B.1.9 Control and Instrumentation The plant shall be controlled by a DCS. Start-up, shutdown and defined operating modes shall all be automatic with facilities for local and remote control. A comprehensive alarm handling system and event logging system shall also be incorporated. Interface with the DCS will be by fibre optic communication links. The level of C&I integration with the remote control room of the operator of the offshore transportation infrastructure needs to reflect future operational and contractual requirements; however safety interlocking and remote instrumentation will be required as a minimum. The control room will be integrated with the remote control room facilities located elsewhere as specified by the operator. MS of 87 i-xx-05905

46 B.1.10 Metering The intention is to provide a fiscal metering station at a point downstream of the inlet battery limit, where it can be shown that there is no chemical or physical process between the battery limit and the metering station or the metering station and the entrance to the offshore pipeline infrastructure that is able to change the composition of the CO₂. Parameters expected to be measured shall include the temperature and pressure, the composition and the mass or volumetric flow. The accuracy of the metering shall be such that it meets the requirements for fiscal measurements relating to the credits for non-emission of the CO 2 to air, and any other commercial or contractual requirements. B.1.11 Cooling Systems Cooling systems are limited to lube oil cooling and the control block. No further cooling of the CO 2 will be required after the booster pumps prior to CO 2 going into the offshore infrastructure as the pipeline materials have been selected such that they can handle supercritical CO 2 and that the CO 2 will cool down rapidly to ground temperatures and offshore sea temperatures of 14 deg C in the summer and 4 deg C in the winter within a short distance of the overall pipeline from the Booster Station. Ambient operating conditions provided will be used for initial design calculations. B.1.12 Noise All new equipment installed as a part of this work shall have, by design, a noise level such that at the Booster Station boundary fence, it is consistent with the requirements of the Environmental Health Officer. For the purposes of this study it shall be assumed as 70dBA. B.1.13 Safety Systems All indoor equipment shall be assumed to have fire detection systems linked to the proposed remote control facility, All mechanical and electrical plant shall be assumed to have automatic fire extinguishing equipment of an appropriate type, which shall be such that minimal damage will be caused to equipment adjacent to the seat of the fire and designed to minimise the ingress of environmentally harmful materials into watercourses, All indoor areas shall have CO₂ detection devices. Depressions below ground level shall be avoided to minimise the accumulation of escaping CO₂, and low level ventilation shall be provided, All buried pipes shall have pipe markers placed at intervals not exceeding 10m, and be subject to a dial before you dig policy. Buried pipes underneath areas of transient high loads (e.g. roadways) shall have additional load-bearing measures installed above (e.g. concrete slabs), or have secondary containments (e.g. pipe-within-a-pipe), All above ground high pressure pipes shall be frequently supported and be clearly labelled at intervals not exceeding 2m to show that they contain high pressure CO₂. MS of 87 i-xx-05905

47 B.1.14 No security measures are assumed to be required additional to those already in place on the TATA site. An additional security fence with a minimum height of 2m shall be installed around the complete Booster Station compound. Design Standards All CCS pressure boosting pumps and equipment will be designed in accordance with the relevant standards and codes. The following high level standards and codes shall, inter alia, apply to the facility: BS PD 8010 Part 1 Code of practice for pipelines Part 1 Steel pipelines on land, noting that CO₂ in this context shall be treated as a Category E fluid (Table 1), Institute of Petroleum Pipeline Code IP6, BS EN Petroleum and Natural Gas Industries, Pipeline Transportation Systems, noting that the HSE recommends that any pipelines designed to BS EN should be supported by good industry practice as presented in BS PD 8010 Part 1, BS 6739:2009 Code of practice for instrumentation in process control systems: installation design and practice, BSI (2000). BS EN Workplace atmospheres electrical apparatus used for the direct detection and direct concentration measurement of toxic gases and vapours. Part 1: General requirements and test methods, BS EN Workplace atmospheres Electrical apparatus used for the direct detection and direct concentration measurement of toxic gases and vapours. Part 2: Performance requirements for apparatus used for measuring concentrations in the region of limit values., BS EN Workplace atmospheres - Electrical apparatus used for the direct detection and direct concentration measurement of toxic gases and vapours. Part 3: Performance requirements for apparatus used for measuring concentrations well above limit values., BS EN Workplace atmospheres - Electrical apparatus used for the direct detection and direct concentration measurement of toxic gases and vapours. Part 4: Guide for selection, installation, use and maintenance., HSE (1997a) Safe work in confined spaces. Confined Spaces Regulations Approved code of practice, regulations and guidance. L101., HSE (1997b). Monitoring strategies for toxic substances. HSG 173, HSE (1999a) Management of health and safety at work. Management of health and safety at work regulations Approved code of practice and guidance. L21., HSE (1999b) COSHH essentials. Easy steps to control chemicals. Control of substances hazardous to health Regulations. HSG 193., HSE (1999c) Control of major accident hazards Regulations (COMAH), including June 2005 amendments HSE (2002a) EH40/2002 Occupational exposure limits 2002., HSE (2002b) Control of substances hazardous to health (4 th ed). The control of substances hazardous to health Regulations Approved code of practice and guidance. L5., HSE (2002c) Discussion document of occupational exposure limits (OEL) framework., and HSE (2002d) Dangerous substances and explosive atmospheres regulations 2002 (DSEAR). MS of 87 i-xx-05905

48 B.1.15 CO 2 pipeline Specific Design Standards These standards are referenced in Appendix D & Appendix E, using the reference numbers given here [REF 1] DNV RP J202 Design and Operation of CO 2 Pipelines, April 2010 [REF 2] DNV OS-F101 Submarine Pipeline Systems, October 2013 [REF 3] BS PD 8010 Part 1 Code of practice for pipelines Part 1 Steel pipelines on land, noting that CO₂ in this context shall be treated as a Category E fluid (Table 1), [REF 4] BS PD Code of Practice for Pipelines Part 2 Subsea Pipelines [REF 5] Institute of Petroleum Pipeline Code IP6, [REF 6] Pipeline Safety Regulations [REF 7] DNV RP E305 On Bottom Stability Design of Submarine Pipelines [REF 8] DNV RP F103 Cathodic Protection of Submarine Pipelines by Galvanic Anodes [REF 9] ISO : Petroleum and Natural Gas Industries - Cathodic Protection of Pipeline Transportation Systems - Part 2: Offshore Pipelines [REF 10] SPE , Effect of Common Impurities on the Phase Behaviour of Carbon Dioxide Rich Systems: Minimizing the Risk of Hydrate Formation and Two-Phase Flow, A Chapoy, R Burgass, B Tohidi (Hydrafact Ltd & Centre for Gas Hydrate Research, Institute of Petroleum Engineering, Heriot-Watt University), and J M Austell, C Eickhoff (Progressive Energy Ltd). Society of Petroleum Engineers, 2009 MS of 87 i-xx-05905

49 B.2 Route to NGC 5/42 Storage Complex, Specific Basis of Design B.2.1 NGC 5/42 Storage Complex Specific Basis of Design The required conditions for CO 2 delivery are as follows: CO 2 in accordance with specification set out for this TVU project are defined in Document No DC00-SPE Delivered CO 2 at 100 barg on platform Platform height 30 metres above sea level The pipeline route has been developed based on the following criteria: Existing Pipeline route corridor: Where possible the pipeline is routed close to existing pipeline systems. A minimum distance of 1km is to be maintained between existing and proposed pipelines. Alignment: The pipeline route length should be minimised where possible whilst still satisfying all other route criteria. Existing Pipeline and cables: The pipeline route should minimise the number of subsea pipeline and cable crossings. Where crossings are unavoidable, routing of the pipeline should allow a crossing angle of greater than 60. Future Pipelines: Consideration should be given to any known future pipelines. Pipeline Installation: The pipeline route should be such that normal pipelay operations (laybarge) are not precluded and the minimum horizontal radius of curvature should be kept to 2000m. Existing and future offshore wind farms: Consideration should be given to any existing and known future offshore wind farms. MS of 87 i-xx-05905

50 B.3 Route to Shell Goldeneye Storage Complex, Specific Basis of Design B.3.1 Shell Goldeneye Storage Complex Specific Basis of Design The required conditions for CO 2 delivery are as follows: CO 2 in accordance with specification set out for this TVU project are defined in Document No DC00-SPE-0001 Delivered CO 2 at 100 barg on platform Maximum Operating Pressure on platform: 120 barg Design Pressure on Platform: 132 barg Platform height 16 metres above sea level of existing platform (not used, see below). Maximum Flow for converted platform: 138,000 kg/hr (note this is insufficient for either flow regime being considered. Study of transport infrastructure has therefore assumed a larger new platform for 100barg CO 2 delivery to the operating deck of the platform at 30 metres). The pipeline route has been developed based on the following criteria: Existing Pipeline route corridor: Where possible the pipeline is routed close to existing pipeline systems. A minimum distance of 1km is to be maintained between existing and proposed pipelines. Alignment: The pipeline route length should be minimised where possible whilst still satisfying all other route criteria. Existing Pipeline and cables: The pipeline route should minimise the number of subsea pipeline and cable crossings. Where crossings are unavoidable, routing of the pipeline should allow a crossing angle of greater than 60. Future Pipelines: Consideration should be given to any known future pipelines. Pipeline Installation: The pipeline route should be such that normal pipelay operations (laybarge) are not precluded and the minimum horizontal radius of curvature should be kept to 2000m. Existing and future offshore wind farms: Consideration should be given to any existing and known future offshore wind farms. MS of 87 i-xx-05905

51 Appendix C Booster Station C.1 15 mtpy Booster Station Concept: The main case for the design of the Booster Station is based on a 15 mtpy flow regime. The Booster Station is designed to receive CO 2 at pressures ranging from 85 barg to 115 barg with a nominal design point of 100 barg. The Booster Station is designed to overcome offshore pipeline pressure drops so that CO 2 may also be delivered at 100 barg at the top of the storage complex platforms with an acceptable range of 85 barg to 115 barg. The Booster Station is designed to accommodate a number of other services. Pipeline Inspection Gauges (PIGs) from either the SSI CO 2 transport line or the onshore CO 2 pipeline system will be received through separate PIG receiving facilities. The CO 2 will then be combined in the receiving header and put through a fiscal metering station from which data will be used in combination with onshore metering stations at each capture facility to apportion actual CO 2 stored in a registered storage complex. The CO 2 pressure is increased through one of three booster pumps driven by a variable frequency motor to efficiently manage power consumption and desired pressure required to achieve delivery pressure conditions. Lower flow will mean less pressure drop and a lower power consumption to still maintain desired delivery pressure. The control of these pumps will be managed by an offsite control room owned and operated by the CO 2 Transport Infrastructure Owner/Operator or Transport and Storage Complex Owner/Operator. An onsite control room is proposed for onsite inspection and operation during maintenance periods. The final major component within the boundaries of the Booster Station is a PIG Launching Facility to provide pipeline inspection of the offshore system up to the selected storage complex. Figure C.1.1 is a Process Flow Diagram for the main facilities of the Booster Station. The Major Equipment Items are listed in Section C.1.3. Figure C.1.2 provides a view of the proposed layout for the Booster Station. In this layout a number of utility items are shown to support the operation of the Booster Station which are shown in the 15 mtpy Utility Equipment in Section C.1.4. This list includes the Vent Stack, a small compressed air system, a small nitrogen generator, transformers, a backup diesel generator and a small process and potable water system among other items listed. The Booster Station is proposed to be situated on land currently owned by TATA Industries just east of the SSI Hot Metal Line and South of Gare Road. An access gate is located on Gare Road to the TATA site and a further gate with double fencing will surround the Booster Station site. C mtpy Process Flow Diagram See Overleaf C mtpy Booster Station Layout Drawing See Overleaf MS of 87 i-xx-05905

52 MS of 87 i-xx-05905

53 MS of 87 i-xx-05905

54 C mtpy Booster Station Major Equipment List Ref Item No. Notes A-1002 PIG Receiving Facility SSI to receive CO 2 from 400 mm pipeline. A-1001 PIG Receiving Facility Onshore Gathering System to receive CO 2 from 600 mm pipeline 1 Designed in accordance with PD 5500: 2009 Cat 1 Hydrostatically tested in accordance with PD 5500 and PD Designed in accordance with PD 5500: 2009 Cat 1 Hydrostatically tested in accordance with PD 5500 and PD A-1003 Fiscal Metering Package (Pre Pump) for all onshore CO 2. Flow rates min/norm/max 70/1141/1712 ton/h. P-1001 A/B/C CO 2 Booster Pumps (Electric Motor Driven). Flow rates min/norm/max 70/570/850 ton/h for each pump Optional Fiscal Metering Package (Post Booster Pumps) A-1004 PIG Launching Facility to Offshore For a 609 mm line with mm wall thickness. (for Goldeneye Case for a 762 mm line with 28.9 mm wall thickness) 1 Coriolis flow meter type with meter proving loop is recommended for use. 3 3 x 50% configuration (2 duty 1 standby) based on a multistage centrifugal type. Lowest density of inlet fluid is identified as 586 kg/m 3. Lube oil is envisaged to be supplied as part of the pump vendor package should this deem necessary for the lubrication of the moving parts. 0 Coriolis flow meter type with meter proving loop is recommended for use. 1 Designed in accordance with PD 5500: 2009 Cat 1 Hydrostatically tested in accordance with PD 5500 and PD MS of 87 i-xx-05905

55 C mtpy Utility Equipment List Ref Item No Notes X-1001 Compressed Air/Dryer Package (300 Sm3/h for each air compressor) X-1002 Dry Air Receiver Dia x 3.9L, 5 m 3 X-1003 Nitrogen Generation Package (42.5 Sm3/h for each module - no spare as able to receive N 2 by truck) 2 2 x 100% configuration (1 duty 1 standby). One instrument air package consists of rotary screw type air compressor; filters; wet air receiver; dryer units; package control panel. 1 1 x 100% configuration. One nitrogen generation package consists of membrane air separators; filters X-1004 Nitrogen Receiver Dia x 3.9L, 5 m 3 A-1005 Vent Stack (20 metre height, 10 kg/s for peak during normal blowdown) 1 Vent tip nozzle shall be designed to maintain a back pressure at 6-10 barg (8 barg is used in this study). V-1002 Vent Knock Out Drum 1 Requirement of Vent K.O. Drum to be confirmed during FEED. T-1001 Non-Hazardous Open Drain Tank (2.7x2.7x2.7m, 20 m 3 ) P-1004 A/B Non-Hazardous Open Drain Tank Pumps (5 m 3 /hr) 1 The open drain tank collects non- hazardous drainage or spillage mainly on the utilities areas as well as the rainwater. 2 2 x 100% configuration (1 duty 1 standby). V-1001 Closed Drain Vessel (30 m 3 ) 1 The closed drain vessel collects high pressure CO 2 drain mainly from the process area, e.g. Booster Pumps and Pigging facilities during maintenance and shutdown or if equipment leakage occurs. P-1005 Closed Drain Vessel Pump (5 m 3 /hr) T-1002 Service Water Storage Tank 1 20 m 3 P-1006 A/B Service Water Pumps (10 m 3 /hr) 1 The collected process fluids will be pumped back to the Booster Station inlet header on level control or on resumption of normal operation. 2 2 x 100% configuration (1 duty 1 standby). T-1003 Potable Water Storage Tank 1 4 m 3 Continued MS of 87 i-xx-05905

56 Ref Item No Notes P-1008 A/B P-1009 A/B Service Water Backwash Pumps (5 m 3 /hr) Potable Water Pumps (5 m 3 /hr) X-1005 Polyelectrolyte Dosing Unit 1 3 l/hr X-1006 Hypochlorite Dosing Unit 1 3 l/hr X-1007 Backwash Ventilator 1 10 m 3 /hr F-1001 Sand Filter 1 1 m 3 F-1002 Activated Carbon Filter 1 1 m 3 F1003 A/B Diesel Duplex Filter Coalescer 2 T-1005 Diesel Storage Tank m Dia x 7m L P-1012 A/B 2 2 x 100% configuration (1 duty 1 standby). 2 2 x 100% configuration (1 duty 1 standby). Diesel Transfer Pumps 2 2 x 100% configuration (1 duty 1 standby). E-1001 Transformer 11kV/6.6kV 1 Power voltage will be stepped down from 11kV to 6.6kV for booster pump motor operation. E-1002 Transformer 11kV/400V 1 Power voltage will be stepped down from 11kV to 400V for Three Phase & Neutral (TP&N) utility load, small pumps and single phase service at 230V. E-1003 Diesel Generator (Power Back-up) 4,000 kw 1 Back-up measure to ensure full power continuity for up to 24 hour for 5 Mtpy flow in the event of main power supply failure. Required a diesel consumption of about 1 m3/h. E-1004 Local Control Room (12 m L x 8 m W x 4 m H) Assumes larger interruption would also reduce CO 2 flows to station. 1 Control room shall contain switchgear, process control system (PCS), COMMS, etc MS of 87 i-xx-05905

57 C.2 5 mtpy Booster Station Concept The alternate case for the design of the Booster Station is based on a 5 mtpy flow regime. The Booster Station is designed to receive CO 2 at pressures ranging from 85 barg to 115 barg with a nominal design point of 100 barg. The Booster Station is designed to overcome offshore pipeline pressure drops so that CO 2 may also be delivered at 100 barg at the top of the storage complex platforms with an acceptable range of 85 barg to 115 barg. The Booster Station is designed to accommodate a number of other services. Pipeline Inspection Gauges (PIGs) from either the SSI CO 2 transport line or the onshore CO 2 pipeline system will be received through separate PIG receiving facilities. The CO 2 will then be combined in the receiving header and put through a fiscal metering station from which data will be used in combination with onshore metering stations at each capture facility to apportion actual CO 2 stored in a registered storage complex. The CO 2 pressure is increased through one of three booster pumps driven by a variable frequency motor to efficiently manage power consumption and desired pressure required to achieve delivery pressure conditions. Lower flow will mean less pressure drop and a lower power consumption to still maintain desired delivery pressure. The control of these pumps will be managed by an offsite control room owned and operated by the Transport Infrastructure Owner/Operator or Transport and Storage Complex Owner/Operator. An onsite control room is proposed for onsite inspection and operation during maintenance periods. The final major component within the boundaries of the Booster Station is a PIG Launching Facility to provide pipeline inspection of the offshore system up to the selected storage complex. Figure C.1.1 is a Process Flow Diagram for the main process components of the Booster Station and is appropriate for the 5 mtpy case as well. In Section C.2.3 the Major Equipment Items are listed. Figure C.2.2 provides a view of the proposed layout for the Booster Station. In this layout a number of utility items are shown to support the operation of the Booster Station which are shown in the 5 mtpy Utility Equipment in Section C.2.4. This list includes the Vent Stack, a small compressed air system, a small nitrogen generator, transformers, a backup diesel generator and a small process and potable water system among other items listed. The Booster Station is proposed to be situated on land currently owned by TATA Industries just east of the SSI Hot Metal Line and South of Gare Road. An access gate is located on Gare Road to the TATA site and a further gate with double fencing will surround the Booster Station site. C mtpy Process Flow Diagram Same as per drawing in C.1.1 above for 15 mtpy Concept C mtpy Booster Station Layout Drawing MS of 87 i-xx-05905

58 AMEC Project No MS of 87 i-xx-05905

59 C mtpy Major Equipment List Ref Item No Notes A-1002 PIG Receiving Facility SSI to receive CO 2 from 400 mm pipeline. A-1001 PIG Receiving Facility Onshore Gathering System to receive CO 2 from 400 mm pipeline A-1003 Fiscal Metering Package (Pre Pump) for all onshore CO 2. Flow rates 70/399/570 ton/h P-1001 A/B/C CO 2 Booster Pumps (Electric Motor Driven). Flow rates min/norm/max 70/200/285 ton/h for each pump Optional Fiscal Metering Package (Post Booster Pumps) A-1004 PIG Launching Facility to Offshore. For a 457 mm line with 14.3 mm wall thickness. (for Goldeneye Case for a 508 mm line with 20.6 mm wall thickness) 1 Designed in accordance with PD 5500: 2009 Cat 1 Hydrostatically tested in accordance with PD 5500 and PD Designed in accordance with PD 5500: 2009 Cat 1 Hydrostatically tested in accordance with PD 5500 and PD Coriolis flow meter type with meter proving loop is recommended for use. 3 3 x 50% configuration (2 duty 1 standby) based on a multistage centrifugal type. Lowest density of inlet fluid is identified as 586 kg/m3. Lube oil is envisaged to be supplied as part of the pump vendor package should this deem necessary for the lubrication of the moving parts. 0 Coriolis flow meter type with meter proving loop is recommended for use. 1 Designed in accordance with PD 5500: 2009 Cat 1 Hydrostatically tested in accordance with PD 5500 and PD MS of 87 i-xx-05905

60 T-1003 Potable Water Storage Tank 1 4 m 3 Continued C mtpy Utility Equipment List Ref Item No Notes X-1001 Compressed Air/Dryer Package. 300 Sm3/h for each air compressor X-1002 Dry Air Receiver Dia x 3.9L, 5 m 3 X-1003 Nitrogen Generation Package Sm3/h for each module (no spare as able to receive N 2 by truck) X-1004 Nitrogen Receiver Dia x 3.9L, 5 m 3 A-1005 Vent Stack, 20 metre height, 10 kg/s for peak during normal blowdown 2 2 x 100% configuration (1 duty 1 standby). One instrument air package consists of rotary screw type air compressor; filters; wet air receiver; dryer units; package control panel. 1 1 x 100% configuration. One nitrogen generation package consists of membrane air separators; filters 1 Vent tip nozzle shall be designed to maintain a back pressure at 6-10 barg (8 barg is used in this study). V-1002 Vent Knock Out Drum 1 Requirement of Vent K.O. Drum to be confirmed during FEED. 1 The open drain tank collects non- hazardous T-1001 Non-Hazardous Open Drain Tank, 2.7x2.7x2.7m, 20 m 3 drainage or spillage mainly on the utilities areas as well as the rainwater. P-1004 A/B Non-Hazardous Open Drain Tank Pumps, 5 m 3 /hr 2 2 x 100% configuration (1 duty 1 standby). V-1001 Closed Drain Vessel, 30 m 3 1 The closed drain vessel collects high pressure CO 2 drain mainly from the process area, e.g. Booster Pumps and Pigging facilities during maintenance and shutdown or if equipment leakage occurs. P-1005 Closed Drain Vessel Pump, 5 m 3 /hr T-1002 Service Water Storage Tank 1 20 m 3 P-1006 A/B Service Water Pumps, 10 m 3 /hr 1 The collected process fluids will be pumped back to the Booster Station inlet header on level control or on resumption of normal operation. 2 2 x 100% configuration (1 duty 1 standby). MS of 87 i-xx-05905

61 Ref Item No Notes P-1008 A/B P-1009 A/B Service Water Backwash Pumps, 5 m 3 /hr 2 2 x 100% configuration (1 duty 1 standby). Potable Water Pumps, 5 m 3 /hr 2 2 x 100% configuration (1 duty 1 standby). X-1005 Polyelectrolyte Dosing Unit 1 3 l/hr X-1006 Hypochlorite Dosing Unit 1 3 l/hr X-1007 Backwash Ventilator 1 10 m 3 /hr F-1001 Sand Filter 1 1 m 3 F-1002 Activated Carbon Filter 1 1 m 3 F1003 A/B Diesel Duplex Filter Coalescer 2 T-1005 Diesel Storage Tank m Dia x 7m L P-1012 A/B Diesel Transfer Pumps 2 2 x 100% configuration (1 duty 1 standby). E-1001 Transformer 11kV/6.6kV 1 Power voltage will be stepped down from 11kV to 6.6kV for booster pump motor operation. E-1002 Transformer 11kV/400V 1 Power voltage will be stepped down from 11kV to 400V for Three Phase & Neutral (TP&N) utility load, small pumps and single phase service at 230V. E-1003 Diesel Generator (Power Back-up), 4,000 kw E-1004 Local Control Room, 12 m L x 8 m W x 4 m H 1 Back-up measure to ensure full power continuity for up to 24 hour for 5 Mtpy flow in the event of main power supply failure. Required a diesel consumption of about 1 m3/h. Assumes larger interruption would also reduce CO 2 flows to station. 1 Control room shall contain switchgear, process control system (PCS), COMMS, etc MS of 87 i-xx-05905

62 Appendix D Route to NGC 5/42 Storage Complex D.1 Route Investigation The development of the route to Aquifer 5 in Block 42 (5/42) drew on available information from the public domain. The pipeline route is identified taking into account third party pipelines, cables, offshore wind farms and seabed obstructions, which would likely occur along the route. The following information was reviewed to determine the pipeline routes: Admiralty charts Geological survey maps Cable awareness charts Offshore wind farm data UK offshore oil and gas information The determined pipeline route was documented in pipeline route drawings within Appendix A. Coordinates of key points along the pipeline routes are tabulated in the developed route map book of drawings. The following areas are reviewed based on the available information and summarised in this report. Pipeline/cable crossings along the route; Blocks covered by the pipeline route; Obstructions along route corridor; Soil data along the route; Military exercise areas; Firing practice areas (MOD). The proposed route from Teesside to the NGC 5/42 Storage Complex is in a south-easterly direction covering 154 km. As previously discussed and shown in the route maps in Appendix A, there are three pipeline crossings and eight cable crossings along the way. In addition to these there are certain obstacles to be directed around. These include: The EDF Wind Farm located near the shore at Teesside. The proposed pipeline route passes between the area of the wind farm and the CATS Natural Gas Pipeline in a 300 meter corridor. Upon passing the EDF Wind Farm, the route gradually bends northward to set up the crossing for the CATS and Breagh natural gas pipelines. However, further northward there are areas delineated as spoil ground and shown on the map as shaded areas to be avoided. The Submarine Exercise Area either is to be avoided or the pipeline is to be trenched through the area. However there are two communications cables through this area which MS of 87 i-xx-05905

63 requires a substantial raised crossing using concrete mattresses and rock dump cover. This study has proposed to avoid the Submarine Exercise Area all together. D.1.1 There are a significant number of shipwrecks delineated on the maps to be avoided for both historical and safety considerations. The proposed route runs through an MOD surface firing range requiring coordination during pipeline laying operations. Crossing Design Concept Pipeline crossings are required where the proposed pipeline crosses either an existing pipeline or cable respectively. The crossing method shall be designed so that no contact between the new pipeline and the pipeline or cables being crossed is made at any time during new pipeline installation, testing or operation. The minimum vertical separation between the new pipeline and the existing pipelines being crossed shall be 0.3 m [REF 2, Section B.1.15]. As the pipelines to be crossed are in operation, disturbance should be kept to a minimum therefore a bridge arrangement is considered in this study. The concept of the proposed crossing arrangement is shown in Figure D.1.1. Concrete mattresses are proposed as structural support for the new pipeline to maintain minimum clearance at all times. The concrete mattresses proposed for these crossing are 5 m x 5 m and 0.3 m high. The existing pipelines and cables are assumed to be unburied. New Pipeline Rock Dump to cover the voids and the pipeline 0.3m Clearance Min. Concrete Mattress Existing Pipeline Figure D.1.1 Crossing Design Concept Table D.1.1 shows the type of crossings along the pipeline route including pipeline diameters. The table also indicates the number of mattresses required to build the bridge across a pipeline of a certain diameter or a cable. Confirmed out of use cables may be cut with the owner/operators MS of 87 i-xx-05905

64 approval. Voids between mattresses are filled with rock and the new pipeline and mattresses are covered further with rock to avoid any contact with any fishing gear, anchors or other possible hazards. Crossing No. Type of Crossing Existing Pipe/Cable Total No. of Concrete Mattress * Rock Dump (m 3 )* 1 CATS 36in Gas Pipeline BREAGH 20in Gas LANGELED 44in GAS TEESSIDE NORTH EXPORT CANTAT 3 F PANGEA North UK/DMK (Out of use) 0 Cut Cable 0 Cut Cable 7 TEESSIDE SOUTH EXPORT Cable UK-Denmark (Out of use) Cut Cable Cut Cable 9 VSNL North Europe UK-Germany 6 (Conflicting Info on use) CREYKE BECK EXPORT Table D.1.1 Crossings Along Proposed Pipeline Route to NGC 5/42 MS of 87 i-xx-05905

65 D.2 Flow Assurance Prediction of CO2 physical properties in the dense phase is very sensitive to the choice of the equation of state (EOS). Although the fluid is nominally pure CO2, there is the possibility of the presence of impurities and these have an impact upon the bubble point of the dense phase CO 2. Refinement of the EOS for impure CO 2 mixtures through experimentation [REF 10, Section B.1.15] has improved the predictability of the pressure requirements to maintain various CO 2 mixtures in the dense phase thus avoiding two phase flow. Control of the quality of the CO 2 through adherence to the TVU CO 2 specification and the management of the pressure within the pipeline system to be always above the bubble point of the CO 2 mixture is critical to the overall performance of the pipeline system. Flow assurance analysis is to determine what input pressures to the system are required to maintain the CO 2 in the dense phase along the whole route of the system and to deliver the CO 2 at the required delivery pressure. The criteria for pipe diameter sizing are to keep the inlet pressure at the level which minimizes the pipeline cost and keeps the pumping station power requirements within reasonable limits. However sufficient safety margin must also be left in the design pressure. Once the route and length was established, bathymetric data along the route was collected from Admiralty Charts and flow assurance assessed. Figure D.2.1 shows the bathymetric profile for the pipeline from the booster station to the sea surface at the platform. An additional 30 metres in height was added to include the head required to reach the top of the platform and pressure drops were calculated for different pipeline sizes. Figure D.2.1 Bathymetric Profile Along Proposed Pipeline Route to NGC 5/42 MS of 87 i-xx-05905

66 The initial flow assurance calculation for the 5/42 pipeline route for the 15 mtpy and 5 mtpy cases are shown in Table D.2.1. Pipe OD (in) Wall thickness (mm) Flow (mtpy) Inlet Pressure (barg) Arrival Pressure (barg) Failed Table D.2.1 Flow Assurance Results for 15 & 5 mtpy cases The results indicate that for the 15 mtpy case, an 18 inch line required too great an inlet pressure. A 28 inch line would be more costly than a 24 inch line with a moderate inlet pressure requirement. In the case of the 5 mtpy case, the flow assurance indicates that a 16 inch diameter line could provide a similar inlet pressure requirement while the 14 inch line would require too great an inlet pressure. While this step indicates a 16 inch line is preferable for the 5 mtpy case, other considerations discussed below favour the 18 inch line overall. MS of 87 i-xx-05905

67 D.3 Mechanical Design D.3.1 Wall Thickness Calculation Pipeline wall thickness requirements are assessed based on the requirements for pressure containment, collapse and local buckling of PD 8010 part 2, 2004 [REF 4 & 1, 2, Section B.1.15]. D.3.2 Pressure Containment Wall thickness requirements to resist internal pressure loading during operation and hydrotest conditions are derived in accordance with Section 6.4, of PD 8010 and Section 5.4 of DNV RP J202 Design and Operation of CO 2 Pipelines [REF 4 & 1, Section B.1.15]. The corrosion allowance of 3mm for offshore piping and fabrication tolerances are added to the calculated wall thickness. D.3.3 Pipe Collapse Wall thickness requirements to avoid pipe collapse due to external pressure are derived in accordance with Annex G1.2, of PD 8010 [REF 4, Section B.1.15]. The corrosion allowance is added to the calculated wall thickness. D.3.4 Local Buckling During Installation Wall thickness requirements to resist the interaction of external pressure, bending moment and axial force during installation are derived in accordance with Annex G1.4 and G1.6, of PD 8010 [REF 4, Section B.1.15]. D.3.5 Buckle Propagation Wall thickness requirements to avoid propagation buckling during installation are derived in accordance with Annex G1.7, of PD 8010 [REF 4, Section B.1.15]. No corrosion allowance is used. D.3.6 Cathodic Protection For the offshore pipeline the cathodic protection design is derived from the methodology of DNV RP F103 Cathodic Protection of Submarine Pipelines by Galvanic Anodes. [REF. 8] A sufficient amount of the concrete coating is removed from every 12 th pipeline segment to attach the anode. Bracelet anodes should be constructed using Al-Zn-Indium activated bracelet anodes with anode tails being secured using pin brazing to reduce the incidence of copper penetration which can occur with Thermite welding. Due to the size of the pipelines, it is recommended that once secured to the pipeline the anodes are concrete coated with at least 45mm of low density concrete coating in order to protect them from fishing and shipping hazards. As such all anodes will be designed to be flush with the concrete coating, thus minimising potential damage to the anodes. MS of 87 i-xx-05905

68 At the landfall crossing, a monobloc isolation joint should be fitted complete with a solid-state overvoltage protector. The cathodic protection for the onshore section of the pipeline should be by impressed current with the design in accordance with ISO [REF. 9]. D.3.7 On-bottom Stability The stability of a pipeline is dependent on the environmental forces, the submerged weight, and the properties of the seabed soil. Steady currents and wave induced currents impose lift, drag, and inertia forces on pipelines resting on the seabed. Frictional and passive soil resistance, due to embedment, counteract these forces. Hydrodynamic stability of the pipeline is achieved when the soil resistance dominates. The objective of on-bottom stability analysis in this study is to determine the submerged weight (and hence the concrete weight coating thickness) to produce a stable pipeline, and if additional stability measures are required. The analysis is conducted in accordance with DNV RP E305 [REF 7, Section B.1.15]. The Simplified Static Stability Analysis has been used. This RP E305 method is based on a static stability method which ties the classical static design to the generalised RP E305 stability method through a calibration of the two approaches [REF 7, Section B.1.15]. The on-bottom stability analyses consider two conditions: An empty pipe over the installation period A product filled pipe over the operational period For the operating condition a minimum content density of 791kg/m 3 has been assumed. During detailed design a density profile based on a specific composition and operating conditions may be used to optimise the stability design. The installation condition has been simulated using the worst case of: 1 year wave and 10 year current 10 year wave and 1 year current The environmental data used for the operational condition is: 100 year wave and 100 year current In the analysis the pipeline stability is assessed for each individual environmental zone. In order to simplify the analysis, instead of considering various water depths within the zone, mean water depth within the zone is determined and is used to assess the pipeline stability requirement. The lowest MS of 87 i-xx-05905

69 friction factor between the pipeline surface and the seabed soil within the environmental zone is used in the calculation. D.3.8 Results The Flow Assurance calculation indicated that a 16 inch pipe diameter would be sufficient for the 5 mtpy case to NGC 5/42. However, there is an additional requirement for pipelines below 18 inches that they must be buried for the entire length of the pipeline [REF 2, Section B.1.15]. Additionally, the 16 inch seamless wall pipe is nearly as expensive as a standard scheduled 18 inch SAW pipe. Therefore this study has chosen an 18 inch line for the 5 mtpy case and a 24 inch line for the 15 mtpy case to NGC 5/42. All pipeline material is Material Grade X65 or DNV SAW1450F The outcome of the Mechanical Design for the 15 mtpy and 5 mtpy pipelines to NGC 5/42 with respect to wall thicknesses are shown in Table D.3.1 and for concrete coatings and intervention for stability in Table D.3.2 and Table D.3.3 below Annual Flow 15 mtpy 5 mtpy Pipe Diameter (inches / mm) / length 24 / / HDD Onshore minimum (mm) Std. Thickness (mm) Pipe Schedule 1 km Offshore Pipeline minimum (mm) Offshore +3mm Std. Thickness (mm) Pipe Schedule 154 km Table D.3.1 Flow Assurance Results for 15 & 5 mtpy cases KP Range (km) Water Depth Range (m) Recommended Concrete Thickness Concrete Density Recommended Trenching/ Backfilling Condition From to Min Max (mm) (Kg/m 3 ) Pre Trenched and Backfilled Trenched and Backfilled Trenched On seabed On Seabed.0 Table D.3.2 Coating and Intervention Requirements 24 OD Pipeline for 15 MTPY to NGC 5/42 MS of 87 i-xx-05905

70 KP Range (km) Water Depth Range (m) Recommended Concrete Thickness Concrete Density Recommended Trenching/ Backfilling Condition From to Min max (mm) (Kg/m 3 ) Pre Trenched and Backfilled Trenched and Backfilled Trenched On seabed On Seabed Table D.3.3 Coating and Intervention Requirements 18 OD Pipeline for 5 MTPY to NGC 5/42 The estimate for the requirements for Cathodic Protection for the 15 mtpy and 5 mtpy pipelines to NGC 5/42 are shown in Tables D.3.4 and D.3.5 below: Pipeline Segment (km) Type of Anode Anode Thick (mm) Anode Length (mm) Anode Spacing # of Joints Anode Mass (kg) Total No. of Anodes Total Mass (tonnes) 0-40 Square Square Table D.3.4 Anode Requirements for the 24 OD Pipeline for 15 MTPY to NGC 5/42 Pipeline Segment (km) Type of Anode Anode Thick (mm) Anode Length (mm) Anode Spacing # of Joints Anode Mass (kg) Total No. of Anodes Total Mass (tonnes) 0-40 Square Square Table D.3.5 Anode Requirements for the 18 OD Pipeline for 5 MTPY to NGC 5/42 MS of 87 i-xx-05905

71 D.4 Material Take off List D mtpy Case: From above data and for pipeline termination, the following material are required in addition to the Major Equiopment List for the 15 mtpy Booster Station in Appendix C: Item Quantity Additional Specification Remarks 24 inch Sch 80 Onshore HDD pipe 24 inch Sch 60 Offshore pipe 24 inch Sch 60 Offshore pipe 24 inch Sch 60 Riser & Platform piping 1,500m HD-3LPE coating only 50% material margin 36,750m HD-3LPE coating & 75 mm concrete coat 124,950m HD-3LPE coating & 50 mm concrete coat 5% material margin 5% material margin 1,000m HD-3LPE 50% material margin Bracelet Anodes mm long & 50 mm thick 5% material margin Bracelet Anodes mm long & 50 mm thick 5% material margin Concrete Mattressess 330 5m x 5m x 0.3m 3% Margin Rock Dump 3,575 cu m 3 pipeline crossings & 6 cable crossings 24 inch Subsea Issolation Valve 1 off 24 Inch PIG Receiver 1 off 24 inch Metering Station 1 off On Storage Platform Table D.4.1 Material take off list for 15 MTPY to NGC 5/42 All pipelines to have an exterior High Density Three Layer Polyethylene (HD-3LPE) coating applied for corrosion protection (nominally 3mm thick). No internal coating should be applied as this will react with the CO 2 and flake off. There are a number of potentially suitable field joint coating systems available following selection of a 3LPE external coating system. The systems typically involve compatible material applied in moulded, injected, sprayed, tape or heat shrink sleeve forms. Final selection of the field joint coating system should be made during FEED. MS of 87 i-xx-05905

72 D mtpy Case From above data and for pipeline termination, the following material are required in addition to the Major Equiopment List for the 5 mtpy Booster Station in Appendix C: Item Quantity Additional Specification Remarks 18 inch Sch 60 Onshore HDD pipe 18 inch Sch 40 Offshore pipe 18 inch Sch 40 Offshore pipe 18 inch Sch 60 Riser & Platform piping 1,500m HD-3LPE coating only 50% material margin 36,750m HD-3LPE coating & 75 mm concrete coat 124,950m HD-3LPE coating & 50 mm concrete coat 5% material margin 5% material margin 1,000m HD-3LPE 50% material margin Bracelet Anodes mm long & 50 mm thick 5% material margin Bracelet Anodes mm long & 50 mm thick 5% material margin Concrete Mattressess 330 5m x 5m x 0.3m 3% Margin Rock Dump 3,575 cu m 3 pipeline crossings & 6 cable crossings 18 inch Subsea Issolation Valve 18 Inch PIG Receiver 1 18 inch Metering Station 1 1 On Storage Platform Table D.4.2 Material take off list for 5 MTPY to NGC 5/42 MS of 87 i-xx-05905

73 D.5 Commentary on any Major Technical Risks The following issues need to be addressed further during FEED, be adhered to during construction and operation or recognised as impacting the costs of the system and the technical flexibility of the design. During FEED it will be necessary to refine the hydraulic analysis models of the system using full details of the wall thickness, external coatings, burial/trenching specifications, routing and profile data, fluid composition, ambient temperature ranges, cathodic protection and operating scenarios. Furthermore it is recommended that a transient analysis is performed to assist design of the overall control strategy and to study operational aspects such as capacity changes, start-up, shut-down and depressurization. As both pipeline route options will cross charted MOD Practice firing ranges it is recommended that early discussions are entered into with the MOD to determine safety measures that should be put in place during pipeline installation and to ensure continued safe operation of the pipelines once completed. For the Aquifer 5/42 option these discussions should be extended to include further definition of the submarine exercise area to the east of Scarborough. As the worldwide pipeline construction industry will be very busy in the next 3-4yrs it is recommended that the availability and costs of suitable construction vessels is reviewed in detail. With respect to materials selection, many elastomers commonly used for seals in the power generation and oil and gas industries cannot be used for liquid CO 2 as it diffuses gradually into the molecular structure during pressurisation. During a rapid depressurisation the gas expands rapidly within the elastomer in a phenomena referred to as explosive decompression resulting in blistering and cracking of the elastomeric material. This in turn will compromise the seal and create pathways for future leakage. Problems have been reported with the use of standard nitrile, polyethylene, some fluorelastomers, chloroprene, and ethylene-propylene compounds. Careful selection of elastomeric materials is critical. CO 2 booster pumps have been specifically designed with special mechanical seals that are flooded with high pressure nitrogen. A very small portion of nitrogen leaks into the CO 2 at all times keeping CO 2 away from the elastomeric external seal that retains the nitrogen. This eliminates the risk of explosive decompression of the elastomeric seal when the booster pump is isolated and shut off for maintenance. Likewise, a common practice in offshore oil and gas pipeline designs is to install an internal coating to the pipe segments to protect from corrosion before installation and reduce roughness on the interior surface and decrease the friction and resulting pressure losses within the length of the pipeline. However, CO 2 is miscible to polymer based coatings and pressure changes within the pipeline system may cause explosive decompression here as well resulting in the coating flaking off and being transported within the CO 2 to potentially plug injection wells or the pores within the rock of the geological structure reducing the injectivity of the CO 2. MS of 87 i-xx-05905

74 Finally, pressure management within the transport network is critical. In addition to onshore boosting of pressure, offshore pressure boosting may also be required if there is too great a drop in pressure between an onshore booster station and the offshore storage sites such that the delivery pressure is insufficient to inject directly into the geological structures. It will be critical to maintain the pressure upstream of an offshore booster pump or facility significantly above the bubble point to avoid twophase flow, drop out of any dissolved water and any impacts from liquid hammer. Two-phase flow within an onshore or offshore booster pump will cause cavitation within the pump risking significant damage, pump failure and possibly loss of containment of CO 2. Simply maintaining the inlet pressure to any CO 2 booster pump above the bubble point conditions for the CO 2 mixture is sufficient to manage this risk. The Aquifer 5/42 pipeline enters into a sand waves area near the NGC 5/42 injection platform. The orientation of the sand waves is not clear at this phase of the project. It should be noted that the orientation and magnitude of the sand waves should be investigated during the FEED. Drying and pre-commissioning will require the pipelines to be packed with nitrogen. The effect of the N 2 packed line during the introduction of CO 2 during start-up will need to be considered in detail during the next phase of the project. Teesside has available an N2 pipeline network that may be easily extended to the Booster Station either directly or through the proposed onshore CO 2 pipeline network. The CATS natural gas pipeline in the shore approach area attempted to bury the line one meter below the sea bed. However, mudstone was present below the sandy bottom such that a simple trenching plough just road over the top of the mudstone without lowering the pipeline sufficiently. The area was beyond a dredging barge s reach so could not pre-dredge the area. The result was the pipeline was not buried sufficiently to protect it from an anchor dragging incident that caused the CATS line to be shut down for months while inspections and repairs were made. Alternative means for hydraulically or mechanically undercutting mudstone under laid pipelines have been developed and should be investigated for use here to avoid a similar incident in the future. Prior to undertaking FEED, the contractual CO 2 specification would need to be finalised and agreed to ensure risks throughout the system infrastructure are managed. While beyond the scope of this work, the alternative to the termination of the offshore pipelines at the top of the storage complex injection platforms should be investigated. A subsea pipeline end termination (PLET) with PIG receiver with a smaller diameter jumper line to the platform riser pipe and SSIV may be more practical. This concept would enable a simple connection to a pipeline manifold for pipelines coming to or going beyond the storage complex for alternative storage opportunities and would simplify any isolation of the pipeline from the platform in the event of an emergency. This is particularly important to the NGC 5/42 application as the storage complex is incapable of taking all the CO 2 from either flow regime considered within WP6 and additional storage facilities will be required. PLETs and pipeline manifolds must be protected by trawl over structures and covered in dumped rock. MS of 87 i-xx-05905

75 Appendix E Route to Shell Goldeneye CO 2 Storage Complex E.1 Route Investigation The development of the route to the Shell Goldeneye Platform Storage Complex straddling Blocks 14 and 20 drew on available information from the public domain. The pipeline route is identified taking into account third party pipelines, cables, offshore wind farms and seabed obstructions, which would likely occur along the route. The following information is reviewed to determine the pipeline routes: Admiralty charts Geological survey maps Cable awareness charts Offshore wind farm data UK offshore oil and gas information The determined pipeline route was documented in pipeline route drawings within Appendix A. Coordinates of key points along the pipeline routes are tabulated in the developed route map book of drawings. The following areas are reviewed based on the available information and summarised in this report. Pipeline/cable crossings along the route; Blocks covered by the pipeline route; Obstructions along route corridor; Soil data along the route; Military exercise areas; Firing practice areas (MOD). The proposed route from Teesside to the Goldeneye Storage Complex is in a Northerly direction covering 433 km. As previously discussed and shown in the route maps in Appendix A, there are four pipeline crossings and no cable crossings along the way. In addition to these there are certain obstacles to be directed around. These include: The EDF Wind Farm located near the shore at Teesside. The proposed pipeline route passes between the area of the wind farm and the CATS Natural Gas Pipeline in a 300 meter corridor. Upon passing the EDF Wind Farm, the route gradually bends northward paralleling the CATS natural gas pipeline. There are areas delineated as spoil ground and shown on the map as shaded areas to be avoided. MS of 87 i-xx-05905

76 There are a significant number of shipwrecks delineated on the maps to be avoided for both historical and safety considerations. The proposed route runs through an MOD surface firing range requiring coordination during pipeline laying operations. E.1.1 Crossing Design Concept Pipeline crossings are required where the proposed pipeline crosses either an existing pipeline or cable respectively. The crossing method shall be designed so that no contact between the new pipeline and the pipeline or cables being crossed is made at any time during new pipeline installation, testing or operation. The minimum vertical separation between the new pipeline and the existing pipelines being crossed shall be 0.3 m [REF 2, Section B.1.15]. As the pipelines to be crossed are in operation, disturbance should be kept to a minimum therefore a bridge arrangement is considered in this study. The concept of the proposed crossing arrangement is shown in Figure E.1.1. Concrete mattresses are proposed as structural support for the new pipeline to maintain minimum clearance at all times. The concrete mattresses proposed for these crossing are 5 m x 5 m and 0.3 m high. The existing pipelines and cables are assumed to be unburied. New Pipeline Rock Dump to cover the voids and the pipeline 0.3m Clearance Min. Concrete Mattress Existing Pipeline Figure E.1.1 Crossing Design Concept MS of 87 i-xx-05905