NEB APPLICATION
APPENDIX 3.1
Engineering, Construction and Operations
Alberta Clipper Expansion Project Enbridge Pipelines Inc. 3000, 425 – 1 st Street S.W. Calgary, Alberta T2P 3L8
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EXECUTIVE SUMMARY
This document is part of an application to the National Energy Board (“NEB”) by Enbridge Pipelines Inc. (“EPI”) for approval to construct the Canadian portion of the Alberta Clipper Expansion Project (the “Project”). This document describes the proposed design, construction and operation of the Project.
Project Description
The Canadian portion of the Project has two main components:
• a new oil pipeline extending from Hardisty, Alberta to the Canada-United States border near Gretna, Manitoba, a distance of about 1,074 km (667 miles); and
• new pumping, tankage and terminalling facilities for the proposed pipeline.
The proposed pipeline will have an outside diameter (OD) of 914 mm (NPS 36) and an annual capacity of 71,500 m3/d (450,000 bbl/d) for oil transportation.
Nine new pumping facilities will be required in Canada for the pipeline. Eight of the facilities will be located on existing EPI pump station sites and one will be located on a new site. Additionally, new tankage and terminalling facilities will be required at the Hardisty terminal.
Design Standards
The Project falls under the jurisdiction of the NEB. The Project will be designed, constructed and operated in compliance with the latest NEB regulatory requirements. The primary applicable regulations are the NEB Onshore Pipeline Regulations, 1999 (OPR-99) , which incorporate by reference the Canadian Standards Association (“CSA”) Z662-03, Oil and Gas Pipeline Systems . These standards, in turn, reference other standards and publications, which will be followed as appropriate in the design of the Project.
Project Schedule
Subject to receipt of regulatory approvals, the construction of the Project is scheduled to begin in Q2 2008. Construction for the Project is expected to be completed by late Q4 2009. Construction of the tanks at the Hardisty terminal will be undertaken in a phased manner, with completion dates ranging from Q4 2009 to Q4 2012.
Construction Logistics
Local accommodations including existing hotels, motels and recreation vehicle (“RV”) parks will be used to house construction workers. In smaller communities, it may be necessary to supplement existing accommodations with temporary sleeping camps. At locations such as Hardisty, full camps may be required to provide food and lodging for some of the workforce.
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Equipment and material for construction will be transported from major distribution centres by rail and truck using existing infrastructure. Access to the right-of-way (“ROW”) and facilities sites will make maximum use of existing roads. Road upgrading and temporary new access road construction may be required in some areas. Stockpile sites will be located close to existing railway sidings, where practical, and contractor staging areas will be established at strategic locations as required.
System Operation and Maintenance
The pipeline and associated facilities will be operated, controlled and monitored from EPI’s control centre, located near Edmonton.
EPI has an integrity management program that uses various tools to identify, assess and evaluate operational risks applicable to the EPI’s pipelines and facilities. The integrity management program prioritizes maintenance activities or projects to ensure that fitness-for-purpose tolerances are maintained. The pipeline and associated facilities will be fully integrated into EPI’s integrity management program.
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TABLE OF CONTENTS
EXECUTIVE SUMMARY ...... III 1.0 INTRODUCTION ...... 1-1 1.1 Purpose ...... 1-1 1.2 Project Description ...... 1-1 1.3 Project Schedule ...... 1-1 1.4 Regulations, Codes and Standards...... 1-2 1.5 Quality Management ...... 1-2 2.0 CLIPPER PIPELINE ...... 2-1 2.1 Pipeline Route Description ...... 2-1 2.2 Hydraulic Design ...... 2-4 2.3 Pipeline Design...... 2-5 3.0 PUMPING FACILITIES ...... 3-1 3.1 General...... 3-1 3.2 Pumps and Motors ...... 3-1 3.3 Tanks and Terminalling ...... 3-1 3.4 Electrical Systems ...... 3-2 3.5 Piping...... 3-2 3.6 Instrumentation...... 3-3 4.0 CONSTRUCTION ...... 4-1 4.1 General...... 4-1 4.2 Pipeline Construction ...... 4-3 4.3 Pumping Facilities Construction ...... 4-6 4.4 Commissioning...... 4-6 5.0 SYSTEM OPERATIONS ...... 5-1 5.1 General...... 5-1 5.2 Pipeline Systems Control ...... 5-1 5.3 Regional (Field) Operations ...... 5-3 5.4 Routine Maintenance ...... 5-4 5.5 Security Management ...... 5-5 5.6 Emergency Response Plans...... 5-5 6.0 SYSTEM INTEGRITY ...... 6-1 6.1 General...... 6-1 6.2 Pipeline Integrity...... 6-1 6.3 Facilities Integrity...... 6-3 7.0 DECOMMISSIONING AND ABANDONMENT ...... 7-1 APPENDIX A – TABLES ...... 1 APPENDIX B – FIGURES ...... 11 APPENDIX C – CLIPPER PIPELINE ROUTE MAPS ...... 13 APPENDIX D – TYPICAL PIPELINE INSTALLATIONS AND CONSTRUCTION PROCEDURES ...... 15
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LIST OF TABLES
Table 2-1: Summary of Pipeline Route Deviations From Existing EPI ROW...... 2-1 Table 2-2: Geotechnical Conditions Along the Clipper Pipeline Route...... 2-2 Table 2-3: Typical Selected Properties of Oil to be Transported in the Clipper Pipeline ...... 2-4 Table 2-4: Clipper Pipeline – Canadian Pumping Facilities Requirements...... 2-5 Table 2-5: Clipper Pipeline – Design Parameters for Line Pipe...... 2-6 Table 2-6: Clipper Pipeline Scraper Trap Facility Design Parameters...... 2-9 Table 2-7: Minimum Depths of Cover...... 2-9 Table 2-8: Road, Railway and Other Crossings...... 2-10 Table 2-9: Watercourses with Restricted Activity Times on the Clipper Pipeline Route...... 2-11 Table 3-1: Clipper Pipeline – Design Criteria For Pumping Facilities ...... 3-2 Table A-1: Acronyms...... 3 Table A-2: Enbridge Pipeline Inc. Engineering Standards and Guidelines...... 4 Table A-3: Clipper Pipeline – Preliminary List of Block Valve Locations ...... 7 Table A-4: Clipper Pipeline – NEB Concordance Table – Engineering ...... 9
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1.0 INTRODUCTION
1.1 Purpose
This document is part of an application to the NEB by Enbridge Pipelines Inc. (“EPI”) for approval to construct the Canadian portion of the Alberta Clipper Expansion Project (the “Project”).
This document describes the proposed design, construction and operation of the Project.
1.2 Project Description
In Canada, the Project has two main components:
• a new export pipeline extending from Hardisty, Alberta to the Canada-United States border near Gretna, Manitoba, a distance of about 1,074 km (667 miles); and
• new pumping, tankage and terminalling facilities for the proposed Pipeline.
1.2.1 Alberta Clipper Pipeline
The proposed pipeline will have an outside diameter (OD) of 914 mm (NPS 36) and an annual capacity of 71,500 m3/d (450,000 bbl/d) for oil transportation. The design of the pipeline will provide expansion capability to accommodate additional future volumes. The pipeline capacity is expandable by adding additional pumping facilities at existing pump stations. Any expansion option selected would be supported by shippers’ requirements and would be the subject of future regulatory applications.
The pipeline will generally be located in, or alongside and contiguous to, the existing EPI ROW. Four sections of the pipeline route, near Milden, Regina, Kipling and Wawanesa, will deviate away from the existing EPI ROW. The total length of these sections is approximately 98.7 km, of which 76.2 km is contiguous to third party utility corridors and 22.5 km is new non-contiguous ROW.
1.2.2 Pumping Facilities
Nine new pumping facilities will be required in Canada for the proposed pipeline. Eight of these new pumping facilities will be located on existing EPI pump station sites. The new Rowatt pump station will be located near the community of Rowatt, south of Regina.
Additionally, new tankage and terminalling facilities will be constructed at the Hardisty terminal.
1.3 Project Schedule
Subject to receipt of regulatory approvals, the construction of the Project is scheduled to commence in Q2 2008. Construction for the Project is expected to be completed by late Q4 2009. Construction of the
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tanks at the Hardisty terminal will be undertaken in a phased manner, with completion dates ranging from Q4 2009 to Q4 2012.
1.4 Regulations, Codes and Standards
The pipeline and facilities for the Project will be designed, constructed and operated in accordance with applicable regulations, and industry codes and standards.
The Project falls under the jurisdiction of the NEB. EPI will, therefore, comply with the latest NEB regulatory requirements. The primary applicable regulations are the NEB Onshore Pipeline Regulations, 1999 (OPR-99), which incorporate by reference the CSA Z662-03, Oil and Gas Pipeline Systems standard. These standards, in turn, reference other standards that will be followed in the design.
Canadian codes will be used. In the absence of applicable Canadian codes, international codes will be used.
The Project will also be designed and operated to meet the requirements of the most recent versions of EPI’s Engineering Standards and Guidelines , as listed in Table A-2 of Appendix A. These guidelines include EPI’s Environmental Guidelines for Construction (2003) and Waste Management Plan (2004) . All of the documents listed in Table A-2 were previously filed with the NEB.
1.5 Quality Management
EPI will implement a quality management plan for the design and construction of the Project.
The quality management plan will address the planning, design and construction of the pipeline and associated facilities related to the Project. The plan will be implemented to ensure all applicable environmental, regulatory and statutory requirements are met, and to monitor and document evidence of compliance. The effectiveness of this system will be assessed by internal quality audits.
The requirements and expectations for quality management and assurance consistent with OPR-99 will be applied to contractors, subcontractors and suppliers as appropriate.
1.5.1 Design
A design quality management system will be used to monitor the detailed engineering design of the Project. This system will include requirements for design reviews, validations and documentation in the form of engineering design records.
Engineering design records will be compiled progressively throughout the Project life cycle. Quality assurance (QA) of the design process will be established through periodic internal audits.
1.5.2 Materials
A project procurement plan will be used for the requisitioning and procuring of materials, equipment and services for the Project.
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Material and equipment selections will comply with applicable codes and standards, including EPI’s engineering equipment specifications and design concepts. Material specifications will be developed for material and equipment not covered by existing EPI specifications.
The EPI materials quality management system will be applied throughout the material procurement cycle. QA of the material procurement process will be established through periodic internal audits.
1.5.3 Construction and Commissioning
A construction plan will be prepared that will describe the specifications, safety, permitting, environmental, construction, testing, control of materials and quality control requirements applicable during construction of the Project.
EPI’s existing construction specifications for pipelines and facilities will be supplemented with additional specifications where necessary. Welding and non-destructive examination processes will be audited for compliance with the OPR-99.
A comprehensive health and safety plan will be developed for construction of the Project. This plan will address safety requirements, responsibilities and lines of communication during construction and commissioning. All Project field crews will be trained and random internal audits will be carried out to ensure that personnel comply with the health, environmental and safety plan. All field personnel will be provided with a condensed field handbook describing the main features of this plan.
Construction, commissioning and operation of the Project will conform to EPI’s existing environmental guidelines for environmental protection and monitoring.
A commissioning plan for the Project will be prepared and implemented.
1.5.4 Quality Audits
An internal audit plan will be implemented for the Project. The prime objective of audits will be to document compliance. Identified deficiencies will be documented in non-conformity reports or corrective action reports, as appropriate, for resolution and follow-up.
1.5.5 Change Management
EPI’s change management procedure for engineering design and material specifications will apply to the Project.
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2.0 CLIPPER PIPELINE
2.1 Pipeline Route Description
Route maps for the proposed pipeline in Canada are presented in Appendix C. The proposed pipeline will generally be located in, or alongside and contiguous to, the existing EPI pipeline ROW between Hardisty, Alberta and the Canada-United States border near Gretna, Manitoba, a distance of approximately 1,074 km (667 miles). Four sections of the pipeline route, near Milden, Regina, Kipling and Wawanesa, will be located away from the existing EPI ROW. As summarized in Table 2-1, the total length of these sections is approximately 98.7 km, of which 76.2 km is contiguous to third party utility corridors and 22.5 km is new non-contiguous ROW. Localized re-routes away from the existing EPI ROW may also be required adjacent to existing EPI pump stations to accommodate the locations of the new pumping facilities.
TABLE 2-1: SUMMARY OF PIPELINE ROUTE DEVIATIONS FROM EXISTING EPI ROW
Name Approximate Length Contiguous to Third Party Third Party Name and Non-Contiguous (km) Utility Length Contiguous Length a Length (km) (km) (km) Milden 4.7 3.7 Transgas 3.7 1.0 Cochin/Alliance 23.9 Conoco Phillips 1.7 Alliance 0.2 Regina 77.4 72.5 4.9 SaskPower 10.9 CNR 1.3 TCPL 34.5 Kipling 8.7 0 N/A 8.7 Wawanesa 7.9 0 N/A 7.9 Totals: 98.7 76.2 N/A 22.5 Note: aN/A=not applicable
As illustrated in Figure B-1 of Appendix B, the existing pipeline corridor between Hardisty and Gretna traverses a series of glacial till, glacio-lacustrine and glacio-fluvial deposits. Table 2-2 summarizes the characteristics of the near surface deposits along the route.
It is not expected that bedrock will be encountered in the ditch along the pipeline route, except possibly at lower elevations in river and stream valleys.
The route is generally favourable for pipeline construction and no significant geotechnical concerns have been identified. Minor slope instabilities at the Souris River and Deadhorse Creek crossings will be addressed during detailed design.
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TABLE 2-2: GEOTECHNICAL CONDITIONS ALONG THE CLIPPER PIPELINE ROUTE
From To Approximate Topography Surficial Geology (EPI KP) (EPI KP) Length (km) 175 Flat to gently Morainal silty clay till, locally overlain by Glacio fluvial sands 184 9 (Hardisty) rolling and gravels Gently rolling to Ice contact deposits, sand, silt and gravel over silty clay till. 184 198 14 hummocky Locally overlain by eolian sand. Flat to gently 198 213 15 Morainal deposits, silty clay till rolling Glacio lacustrine and glacio fluvial deposits, sand, silt and Flat to gently 213 260 47 gravel over silty clay till. Locally overlain by eolian sand, and rolling alluvial sand and gravel deposits. Gently rolling to 260 270 10 Morainal deposits, silty clay till hummocky 270 279 9 Gently rolling Glacio lacustrine deltaic, silt and clay, over silty clay till Flat to gently 279 297 18 Glacio lacustrine plain, silt and clay over silty clay till rolling Flat to gently 297 322 25 Morainal plain, with some kettled features, silty clay till rolling Flat to gently 322 325 3 Glacio lacustrine plain, silt and clay rolling Flat to gently 325 338 13 Glacio fluvial plain, sand and gravel rolling Flat to gently 338 351 13 Glacio fluvial plain, sand and gravel overlying silty clay till rolling 351 362 11 Undulating Morainal plain, silty clay till Flat to gently 362 390 28 Glacio lacustrine plain, silt and clay rolling Eagle Creek valley, flat to Glacio lacustrine deltaic and alluvial floodplain deposits, gravel, 390 395 5 moderate sand, silt and clay slopes Flat to gently 395 422 27 Glacio lacustrine plain, silt and clay rolling Eagle Creek valley, flat to Glacio lacustrine deltaic and alluvial floodplain deposits, gravel, 422 426 4 moderate sand, silt and clay slopes Flat to gently 426 465 39 Glacio lacustrine plain, silt and clay rolling Macdonald 465 468 3 Creek, flat to Glacio fluvial plain, gravel, sand and silt sloping 468 472 4 Flat Glacio lacustrine plain, silt and clay Flat to gently 472 480 8 Morainal plain, silty clay till rolling 480 498 18 Flat to Morainal, locally kettled, silty clay till
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From To Approximate Topography Surficial Geology (EPI KP) (EPI KP) Length (km) hummocky Sloping, South Saskatchewan Glacio lacustrine deltaic and alluvial floodplain deposits, gravel, 498 515 17 River, flat to sand, silt and clay sloping Gently rolling to 515 554 39 Morainal, kettled, silty clay till hummocky Flat to gently 554 566 12 Glacio fluvial plain, sands and gravel over silty clay till rolling Gently rolling to 566 584 18 Morainal, kettled, silty clay till hummocky Flat to gently 584 600 16 Glacio fluvial plain, sand and gravel over silty clay till rolling Flat to gently 600 613 13 Glacio lacustrine deltaic, sand, silt and clay rolling 613 618 5 Flat to ridged Glacio fluvial sand and gravel 618 625 7 Hummocky Morainal silty clay till over glacial fluvial sand and gravel Gently rolling to 625 653 28 Morainal plain, silty clay till hummocky Qu’Appelle Glacio lacustrine deltaic, Glacio fluvial and alluvial deposits, 653 676 23 Valley, flat to gravel, sand, silt and clay sloping Flat to gently 676 730 54 Glacio lacustrine plain, silt and clay rolling Gently rolling to 730 737 7 Glacio lacustrine and Glacio fluvial, gravel, sand, silt and clay hummocky Flat to 737 780 43 Morainal, silty clay till. Locally kettled hummocky 780 794 14 Flat to rolling Glacio fluvial plain, gravel and sand over silty clay till Flat to 794 854 60 Morainal, silty clay till, moderately kettled hummocky Flat to gently 854 874 20 Glacio lacustrine, silt and clay rolling Gently rolling to Morainal, silty clay till, may contain cobbles and boulders. 874 980 106 hummocky Overlain discontinuously by thin lacustrine silt and clay Flat to gently Glacio lacustrine silt and clay ranging up to 20 m in thickness. 980 1040 60 rolling Underlain by silty clay till Silty clay till, ranging up to 25 m in thickness. May contain 1040 1062 22 Hummocky cobbles and boulders Flat to gently 1062 1080 18 Glacio lacustrine clay rolling Flat to gently Glacio fluvial and alluvial sands and gravels underlain by silty 1080 1122 42 rolling clay till Morainal silt till, overlain locally with Glacio fluvial sand and 1122 1132 10 Gently rolling gravel 1132 1143 11 Gently rolling to Glacio fluvial, gravel, sand and silt, overlying silty clay till.
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From To Approximate Topography Surficial Geology (EPI KP) (EPI KP) Length (km) hummocky Gently rolling to Morainal, silty clay till, may contain cobbles and boulders. 1143 1200 57 hummocky Overlain locally by thin lacustrine deposits of silt and clay 1200 1220 20 Flat Glacio lacustrine, clay 1245 1220 25 Gently rolling Alluvial deposits, gravel and sand (border)
2.2 Hydraulic Design
A hydraulic analysis of the entire Alberta Clipper Pipeline from Hardisty, Alberta to Superior, Wisconsin, a distance of approximately 1,593 km (990 miles), was undertaken to determine the optimum combination of pipeline size and pump discharge pressures that would achieve an annual capacity of 71,500 m 3/d (450,000 bbl/d) for oil.
Table 2-3 summarizes the typical properties of the heavy crude oil that will be transported in the proposed pipeline.
TABLE 2-3: TYPICAL SELECTED PROPERTIES OF OIL TO BE TRANSPORTED IN THE CLIPPER PIPELINE
Property Heavy Crude Specific gravity 0.935 Vapour pressure (kPa) 0 Viscosity at 10°C (cSt) 350 Viscosity at 21°C (cSt) 177
The proposed pipeline will operate as a batch pipeline. Consequently, the hydraulic analysis assumed that the product with the highest viscosity would govern the flow rate in the proposed pipeline. The flow rate along the pipeline must be constant at all locations and therefore the pump discharge pressure at each pump station will vary depending on the viscosity of the oil that is passing through that particular pump station.
The hydraulic analysis assumed that all new pumping facilities for the proposed pipeline would be located on existing EPI pump station sites, except for the new Rowatt pump station. A series of analyses were carried out in which the pipeline diameter and maximum operating pressure (MOP) were varied in order to determine an optimum combination that would achieve the annual capacity.
The hydraulic analysis found that the optimized design was a 914 mm OD (NPS 36) pipeline with nine pumping facilities in Canada. The pipeline capacity is expandable by adding additional pumping facilities at existing pump stations. Any expansion option selected would be supported by shippers’ requirements and would be the subject of future regulatory applications.
Table 2-4 shows the locations of pumping facilities and pump horsepower (HP) required at each location in Canada.
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TABLE 2-4: CLIPPER PIPELINE – CANADIAN PUMPING FACILITIES REQUIREMENTS
Station Approximate MOP of Required VFD Location Discharge Pipe Pump Power (HP) (EPI KP) (kPa) (HP) Hardisty 175.4 9,930 4 x 5,500 1 x 5,500 Kerrobert 351.3 9,930 2 x 5,500 1 x 5,500 Milden 475.0 9,930 2 x 5,500 1 x 5,500 Craik 590.7 9,930 2 x 5,500 1 x 5,500 Rowatt (new) R38.9 a 9,930 2 x 5,500 1 x 5,500 Glenavon 812.1 9,930 2 x 5,500 1 x 5,500 Cromer 958.8 9,930 2 x 5,500 1 x 5,500 Glenboro 1103.3 9,930 2 x 5,500 1 x 5,500 Gretna 1242.4 9,930 2 x 5,500 1 x 5,500 Note: aDenotes that the location is on the Regina re route.
2.3 Pipeline Design
2.3.1 General
The proposed pipeline will be designed as described in the following sections and in accordance with the applicable codes and regulations. The pipeline will be designed and operated as a low vapour pressure (LVP) pipeline.
2.3.2 Line Pipe
Line pipe for the proposed pipeline will be made of low carbon, high strength, low alloy Grade 483 (X70) steel and will be produced by a longitudinal or helical seam welding process. The line pipe will be manufactured to CSA Z245.1 or American Petroleum Institute (API) standard API 5L.
Table 2-5 summarizes the design parameters and estimated quantities of line pipe required for the pipeline. Additionally, the proposed pipeline will contain short lengths of heavy-wall pipe where they are required for crossings of roads and major rivers. The length and wall thicknesses of these additional heavy-wall applications will be determined based on engineering assessments performed during detailed design.
The feasibility of using Grade 550 (X80) steel and associated reduced wall thicknesses for all, or a portion, of the proposed pipeline will be evaluated during detailed design.
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TABLE 2-5: CLIPPER PIPELINE – DESIGN PARAMETERS FOR LINE PIPE
Design Parameter Line Pipe Line Pipe Line Pipe OD (mm) 914 914 914 CSA notch toughness category 1 1 1 MOP (kPa) 7,710 8,060 8,390 Design factor 0.8 0.8 0.8 CSA location factor 1 1 1 Minimum design temperature 5 5 5 (°C) Steel grade (MPa) 483 483 483 Minimum wall thickness (mm) 9.12 9.53 9.92 Estimated quantity (km) 414.2 199.2 149.5
Design Parameter Line Pipe Line Pipe Uncased Railway Crossings OD (mm) 914 914 914 CSA notch toughness category 1 1 1 MOP (kPa) 8,720 9,060 7,718 9,060 Design factor 0.8 0.8 0.8 CSA location factor 1 1 0.625 Minimum design temperature 5 5 5 (°C) Steel grade (MPa) 483 483 483 Minimum wall thickness (mm) 10.31 10.72 14.59 17.15 Estimated quantity (km) 280.1 29.5 1.5
2.3.3 Class Location
The proposed pipeline will transport oil and will therefore be designed and operated as a LVP pipeline. As specified in Table 2-4 of CSA Z662-03, a class location factor of 1.0 can be used at all locations for the design of LVP pipelines (except for uncased railway crossings where the class location factor must be reduced to 0.625).
2.3.4 Welding
Field girth welding of line pipe for the proposed pipeline will be by manual shielded metal arc welding (SMAW) or mechanized gas metal arc welding.
The tie-in welding for the proposed pipeline will involve a combination of manual SMAW and semi-automatic flux core arc welding. All field girth welds will be non-destructively inspected using ultrasonic or radiographic inspection methods.
A joining program will be developed consistent with OPR-99 and welders will be qualified in accordance with the requirements of CSA Z662-03.
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2.3.5 Protective Coatings
The primary external corrosion control for the proposed pipeline will be provided by a fusion bonded epoxy (FBE) coating that will be applied at a pipe coating plant.
Line pipe for horizontal directional drilled (HDD) or bored sections of the pipeline may receive an additional abrasive resistant coating to protect the FBE coating. During construction, rock shield, sand padding, wooden lagging or concrete coating will be used where required to provide additional mechanical protection for the pipe coating.
Field girth welds will be coated with a system compatible with the plant-applied FBE coating. Buried block valve assemblies will be coated with a suitable corrosion control system such as an epoxy/urethane system.
The proposed pipeline will not transport hydrocarbons containing significant corrosive properties and therefore an internal pipe coating will not be required.
2.3.6 Cathodic Protection
Cathodic protection (CP) will be used as a secondary corrosion control measure for the proposed pipeline. The CP system will be designed and installed in accordance with the applicable codes, regulations, and EPI procedures and operating practices. Monitoring of the CP system will be ongoing, and in accordance with CSA Z662-03 and Canadian Gas Association (CGA) standard OCC-1-2005. When portions of the pipeline are near or parallel to alternating current power lines, the requirements of CSA Z662-03 and Can/CSA-C22.3 No. 6 will be met.
The proposed pipeline will share a common ROW with several existing pipelines. The pipeline will be made electrically continuous with these existing pipelines using continuity bonding. This electrical continuity will provide common CP to all of the pipelines. Continuity bonding will be provided by means of multiple negative cables at the CP locations and at other intermediate bond locations as required.
Test stations and coupon test stations will be installed at appropriate intervals along the pipeline to confirm the effectiveness of the applied CP current and to permit pipeline access for other corrosion control monitoring activities. Test stations will also be installed at cased road and railway crossings, if present, and at foreign pipeline crossings, as necessary.
The CP system for the proposed pipeline will be electrically isolated from the CP system used at the pump station sites. Monolithic (weld-in type) isolators will be installed where the pipeline enters and exits pump stations. Standard flange insulation kits will be employed to isolate drain lines or other piping that may bypass the mainline insulation.
2.3.7 Valves and Fittings
Block valves and check valves will be installed along the pipeline and meet the requirements of CSA Z662-03, Clause 4.4.
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Valve locations will generally coincide with the locations of the existing valves along EPI’s pipeline corridor. Table A-3 in Appendix A is a preliminary list of block valve locations for the pipeline. The locations of the valves on the pipeline, and the potential use of check valves at some locations, will be finalized during detailed design and will use EPI’s operational risk management process to assess the requirement for additional valves based on environmentally sensitive areas, potential accidental release volumes, and operation and maintenance requirements.
All mainline pipeline valves on the proposed pipeline will be full-port valves with electric motor operators. Electrical power for valves will be obtained from local utility companies where possible, or from alternative power sources.
The design, manufacture and testing of all valves and fittings will be completed in accordance with the requirements of CSA Z662-03. All valves and fittings will be compatible with the line pipe to which they are connected.
2.3.8 Scraper Trap Facilities
Scraper trap facilities will be installed on the pipeline at the Hardisty, Kerrobert, Rowatt, Cromer and Gretna stations. The scraper trap facilities will be capable of launching and receiving the latest models of in-line inspection tools, as well as standard scrapers used for batching, cleaning and pipeline integrity verification.
The scraper trap end closures will be swing-type, with a pressure interlock protective system to safeguard against the door being opened when the trap is pressurized (as specified in CSA Z662-03). The pipe and barrel sections of the scraper trap assemblies will be made of either low carbon, high strength, low alloy steel or quenched and tempered carbon steel, and will be produced as seamless pipe, or from formed pipe or rolled plate. The selection of materials will be determined during detailed design. The pipe will be manufactured to CSA 245.1 standards.
Table 2-6 lists design parameters for the scraper trap facilities for the proposed pipeline. The barrel OD, material grade and wall thicknesses for the various components of the scraper trap facilities may change depending on the particular manufacturer.
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TABLE 2-6: CLIPPER PIPELINE SCRAPER TRAP FACILITY DESIGN PARAMETERS
Design Parameter Hardisty Kerrobert, Gretna Line Pipe Barrel Pipe Line Pipe Barrel Pipe OD (mm) 914 1,016 914 1,016 CSA notch toughness category 1 1 1 1 MOP (kPa) 9,060 9,060 8,720 8,720 Design factor 0.6 0.6 0.6 0.6 CSA location factor 1 1 1 1 Scraper trap pressure rating PN100 PN100 PN100 PN100 Minimum design temperature (°C) 45 45 45 45 Steel grade (MPa) 483 483 483 483 Minimum wall thickness (mm) 14.29 15.88 13.75 15.29
Design Parameter Rowatt Cromer Line Pipe Barrel Pipe Line Pipe Barrel Pipe OD (mm) 914 1,016 914 1,016 CSA notch toughness category 1 1 1 1 MOP (kPa) 7,710 7,710 8,390 8,390 Design factor 0.6 0.6 0.6 0.6 CSA location factor 1 1 1 1 Scraper trap pressure rating PN100 PN100 PN100 PN100 Minimum design temperature (°C) 45 45 45 45 Steel grade (MPa) 483 483 483 483 Minimum wall thickness (mm) 12.16 13.52 13.23 14.71
2.3.9 Minimum Depths of Cover
The minimum installation depths of cover for the pipeline will comply with applicable codes and are summarized in Table 2-7.
TABLE 2-7: MINIMUM DEPTHS OF COVER
Location Minimum Depth Minimum Depth of of Cover in Soil Cover in Rock (m) (m) General 0.9 0.6 Paved roads 1.5 1.2 Railways 2.0 2.0 Watercourses 1.2 0.6
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2.3.10 Pipeline Crossings
The proposed pipeline will cross below existing highways, roads, railway lines, foreign pipelines and utility lines. Table 2-8 lists the approximate number of crossings. All crossings will be designed and constructed to conform to current NEB regulatory requirements.
TABLE 2-8: ROAD , RAILWAY AND OTHER CROSSINGS
Crossing Description Approximate Number Major highway crossings 66 Minor road crossings 847 Railway crossings 31 Foreign pipeline crossings 160 Other utility line crossings 58 Total: 1,162
The loads imposed on the line pipe by road and rail traffic will be considered in the design of these crossings.
Generally, bored crossings will be used below paved highways and railway lines to avoid traffic disruptions. However, in locations where the pipelines cross unpaved roads that carry very low traffic volumes, consideration will be given to constructing the crossings using conventional open cut procedures.
Foreign pipelines and utility lines will be crossed using several techniques, including boring and open cut.
2.3.11 Watercourse Crossings
The proposed pipeline will cross approximately 71 watercourses. Watercourse crossing locations are shown on the environmental alignment sheets included in the Environmental and Socio-Economic Assessment (ESA) and filed as part of this application. Conventional open cut or isolated crossing techniques can be executed at any time of year at all watercourse crossings, except for the 17 crossings listed in Table 2-9. The information contained in the table will be finalized during detailed design.
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TABLE 2-9: WATERCOURSES WITH RESTRICTED ACTIVITY TIMES ON THE CLIPPER PIPELINE ROUTE
Name Approximate Restricted Activity Location Period (EPI KP) Eyehill Creek 272.2 April 16 to June 30 Eagle Creek 393.6 April 1 to May 31 Eagle Creek 426.0 April 1 to May 31 South Saskatchewan River 505.6 Oct. 1 to July 15 Qu’appelle River 657.1 April 1 to May 31 High Hill Creek 666.9 April 1 to May 31 Wascana Creek R45.5 a April 1 to May 31 Pipestone Creek 951.6 April 1 to June 15 Souris River 1073.4 April 1 to July 31 Spring Brook W4.2 b April 1 to June 15 Oak Creek 1087.0 April 1 to June 15 Oak Creek 1109.3 April 1 to June 15 Oak Creek 1110.3 April 1 to June 15 Cypress River 1120.1 April 1 to June 15 Cypress River 1131.5 April 1 to June 15 Thornhill Coulee 1186.3 April 1 to June 15 Deadhorse Creek 1196.6 April 15 to June 15 Notes: aDenotes that the location is on the Regina re route. bDenotes that the location is on the Wawanesa re route.
With the exception of the South Saskatchewan, Qu’appelle and Souris Rivers, all watercourses (when water is present during construction) will be crossed using an isolated trenching technique outside the in-stream restricted activity period, if applicable, unless otherwise approved by provincial and federal fisheries authorities. The feasibility of completing a trenchless or an isolated trenched crossing of the South Saskatchewan, Qu’appelle and Souris Rivers will be evaluated during detailed design and a report will be submitted to the NEB.
2.3.12 Buoyancy Control
Buoyancy control may be needed along sections of the pipeline located under watercourses and in areas where the water table is high. Screw anchors, pipe weights, concrete coating or all three will be used to provide buoyancy control, as necessary. The most suitable buoyancy control method depends on site-specific conditions at each location and will be determined during detailed design.
2.3.13 Pressure Testing
At the time of this publication, it is planned that the pipeline will be hydrostatically pressure tested in accordance with the requirements of OPR-99 and CSA Z662-03. Before hydrostatic pressure testing, a testing program will be developed and provided to the NEB as required.
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During detailed design, the feasibility of implementing an alternative integrity validation (AIV) as an alternative to hydrostatic pressure testing of the pipeline will be evaluated.
2.3.14 Signs and Markers
Appropriate signs will be placed to warn the public, any third party utility companies and others of the presence of the pipeline. Warning signs will be placed as follows.
• where the pipeline enters and exits road and highway ROWs;
• on the support posts of the chainage markers installed at predetermined intervals along the pipeline route;
• adjacent to intersections with foreign pipelines and buried utility lines;
• back from the top of the bank on both sides of watercourse crossings;
• directly above the pipeline on any fencelines that are crossed; and
• on all posts installed to support CP test lead junction boxes.
2.3.15 Unspecified Conditions
Localized conditions along the proposed pipeline route that may be present and that are not specifically addressed in CSA Z662-03 include slope instability, watercourse scour and blasting adjacent to existing facilities. Seismic induced loading is not expected to be a design issue for the pipeline.
During detailed design, qualified professional engineers will assess, prepare and certify designs to safeguard the existing pipelines from the potential effects of these and other conditions that are not specifically addressed in CSA Z662-03.
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3.0 PUMPING FACILITIES
3.1 General
New pumping facilities will be required for the proposed pipeline in Canada at Hardisty, Kerrobert, Milden, Craik, Rowatt, Glenavon, Cromer, Glenboro and Gretna. Additionally, new tankage and terminalling facilities will be required at the Hardisty terminal. Eight of the pumping facilities, and the tankage and terminalling facilities, will be located on EPI’s existing pump station and Hardisty terminal sites. The Rowatt pumping facility will be located on a new site and will require new land.
Figures B-2 to B-10 in Appendix B illustrate the proposed layouts for the new pumping facilities at each station. As indicated, the new pumping facilities will be located separately from the existing pumping facilities. Figure B-11 in Appendix B illustrates the location of the initial two tanks to be constructed at the Hardsty terminal. The locations for the facilities will be finalized during detailed design.
3.2 Pumps and Motors
Electrically powered centrifugal pumps, connected in series, will be used for the proposed pipeline. Table 2-4 summarizes the number and HP of the pumps necessary to achieve the design capacity for the pipeline.
All new pumping units will be installed outdoors.
Figure B-12 to Figure B-14 in Appendix B are typical process flow diagrams (“PFDs”) for the pumping facilities. The actual arrangement to be used for each pumping facility will be determined during detailed design.
Pressures and flow rates for the new pumping facilities will be controlled from EPI’s Edmonton control centre, and at station unit and pump control panels. Pressure control valves (“PCVs”) will be provided on the discharge side of the pumps to provide secondary station pressure control.
To improve efficiency and start-up the mainline pumping units, one Variable Frequency Drive (“VFD”) will be installed at each of the pump stations. The VFD will also be used to provide primary station pressure control.
3.3 Tanks and Terminalling
A total of six new 200,000 barrel working volume (250,000 barrel nominal) oil storage tanks will be required at the Hardisty terminal. Construction of the tanks will be phased over a four-year period to match the throughput forecast. Two in-service tanks will be required by Q4 2009, a third tank by Q4 2010, a fourth tank by Q4 2011 and the final two tanks by Q4 2012. Tank lots, secondary containment, access roads and fire protection systems will be expanded to accommodate new tanks.
Existing shipper delivery connections into the Hardisty terminal will be modified, existing transfer manifolds will be expanded, and additional booster pumps will be added to feed the new pipeline initiating station. A new manifold and tank lines connecting the new tanks will be required.
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An expansion of the injection metering will be required. Existing metering manifold 104 will be expanded with the addition of three 406 mm (16”) PD meters. The meters’ limits of error will meet or exceed the +/- 0.25% as specified by Canadian Weights and Measures Regulation Part V Division XI. The meter system accuracy will be enhanced with the use of the existing bi-directional meter prover and flow computer. Fluid analysis will be conducted with various instruments including viscometer, densitometer, and an automatic sampler assembly to determine all pertinent fluid properties.
A new booster pump manifold will feed from the new tankage to the initiating pump station at Hardisty.
3.4 Electrical Systems
Electrical power for the new pumping facilities will generally be obtained from the local electrical utility providers.
New electrical services buildings, about 10 m by 15 m in plan view, will house medium voltage equipment for pump motors, 480 V motor control centres (MCCs), VFDs, control systems, uninterruptible power supply (UPS) units and miscellaneous equipment. The electrical services buildings will consist of prefabricated modular units with all electrical equipment installed before they are shipped to each pump station site.
The electrical system will be designed to allow the 4,160 V motor buses and the 480 V utility buses to remain isolated from one another so that they function as independent systems.
The UPS systems will be designed to maintain critical control and shutdown equipment operability in the event that the primary electrical supply is interrupted.
3.5 Piping
Piping at the new pumping facilities will be designed in accordance with the parameters summarized in Table 3-1.
All piping will be made of low carbon, high strength, low alloy steel. Large bore piping wall thicknesses will range from 8.2 to 17.5 mm. Welding of pipe joints at pumping facilities will use a combination of SMAW and semi-automatic flux core arc welding. Welding specifications and procedures will be developed and welders will be qualified in accordance with the requirements of OPR–99 and CSA Z662-03.
TABLE 3-1: CLIPPER PIPELINE – DESIGN CRITERIA FOR PUMPING FACILITIES
Design Parameter Value MOP (kPa) 9,930 Pressure class PN100 Design factor 0.6 Minimum design temperature 45°C Steel grade (MPa) 359 to 483
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All major equipment and piping for the pumping facilities will be above ground, except for sump tanks. Corrosion control measures will include painting all equipment and facilities. CP will be provided for underground steel components.
Thermal relief valves will be provided to protect piping and equipment connected to the pumping facilities. Thermal relief valve discharges will be drained to oil sumps, which will also collect fluids from equipment drains. Recovered oil from the sumps will be injected into the inlet side of the pumps.
All designs for pressure vessels will be registered in accordance with CSA B51-03. All qualifying pressure vessels or fittings are pre-designed and registered for commercial distribution in Canada. Vessels or fittings may include, but are not necessarily limited to, hydraulic accumulators for valve actuators and nitrogen bottles for pressure surge relief valves.
3.6 Instrumentation
The following instrumentation and controls will be provided for each of the pumping facilities.
• a computer-based control system; • an ultrasonic flow meter for the material balance system (MBS) at every third station; • PCVs; • a pressure recorder; • pressure transmitters; • temperature transmitters; and • a sump level transmitter (radar).
The electrical services buildings for each new pumping facility will have heat detectors and smoke detectors to detect fires caused by electrical faults, overheating of equipment or other causes. Gas detectors will monitor hydrocarbon leaks.
Enclosed pump and motor shelters, if used, will be equipped to detect the presence of hydrocarbon gases, hydrogen sulphide, heat or flames.
New pumping facilities will be provided with emergency shutdown (ESD) systems.
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4.0 CONSTRUCTION
4.1 General
Construction activities for the Project will include:
• construction of the proposed pipeline from Hardisty, Alberta to the Canada-United States border near Gretna, Manitoba; and
• construction of the associated pumping, tankage and terminalling facilities.
This section describes the construction of all components of the Project. Sketches that illustrate typical pipeline designs and construction procedures are presented in the Environmental and Socio-Economic Assessment section of this Application (Volume II). Appendix D illustrates additional construction procedures.
4.1.1 Construction Contracts
Separate construction contracts will likely be awarded for:
• construction of the proposed pipeline; and
• construction of the associated pumping, tankage and terminalling facilities at Hardisty, and pumping facilities at Kerrobert, Milden, Craik, Rowatt, Glenavon, Cromer, Glenboro and Gretna.
The number of construction spreads and the number of pipeline construction contracts that will be used for construction of the pipeline will be determined during detailed engineering.
It is expected that successful contractors will choose to subcontract some construction activities to qualified subcontractors.
Separate contracts may be awarded to specialist contractors (for example, specialists in HDD, construction surveying, non-destructive testing and pipe hauling and stockpiling).
4.1.2 Construction Schedule
Subject to receipt of regulatory approvals, the construction of the Project is scheduled to begin in Q2 2008. Construction for the Project is expected to be completed by late Q4 2009. Construction of the tanks at the Hardisty terminal will be undertaken in a phased manner, with completion dates ranging from Q4 2009 to Q4 2012.
It is expected that pipeline construction will occur over three consecutive construction seasons – Summer 2008, Winter 2008/2009 and Summer 2009. It is also expected that, to the extent practical, construction activities between Cromer, Manitoba and the Canada-United States border near Gretna, Manitoba will be coordinated with construction activities for the proposed LSr Pipeline, which is part of a separate NEB application for the Southern Lights Project.
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Procurement of long lead time materials and equipment will be scheduled in advance of the construction and installation activities.
4.1.3 Construction Resources
Labour and service requirements, and their associated influence on local communities and infrastructure, will be greatest during the construction phase of the Project. Peak requirements for personnel and services will occur from Q3 2008 to Q4 2009.
A total workforce of between 1,000 and 1,200 workers will be required to construct the proposed pipeline, with work being carried out concurrently on two or three spreads. An additional 200 to 250 workers will be required to construct the new pumping, tankage and terminalling facilities for the pipeline. Personnel will require various skills, ranging from entry-level labourers to highly skilled trades.
Local accommodations including existing hotels, motels and recreation vehicle (RV) parks will be used to house construction workers. In smaller communities, it may be necessary to supplement existing accommodations with temporary sleeping camps. At locations such as Hardisty, full camps may be required to provide food and lodging for some of the workforce.
4.1.4 Construction Logistics
Logistics for the Project will involve the movement of equipment, materials and supplies to staging areas and stockpile sites along the ROW, and to the pump station sites. Equipment and materials will be transported by rail and truck.
In addition to the equipment and materials required for the Project, fuel and other supplies will be procured locally or transported by truck from major distribution centres to equipment storage yards and stockpile areas located near the ROW.
Construction access will make maximum use of existing roads. Road upgrading and temporary new access road construction may be required in some areas.
Equipment storage yards, stockpile sites and staging areas will be located near the ROW, existing roads and railway sidings.
4.1.5 Construction Safety
Contractors will be required to adhere to all local safety regulations, contractor safety manuals, their corporate safety manuals and EPI’s safety manuals.
Safety inspectors will be on site during construction to ensure that all personnel follow safety procedures.
4.1.6 Construction and Environmental Inspections
Qualified personnel will inspect the pipeline and associated pumping, tankage and terminalling facilities installations based on a documented inspection plan. These inspections
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will monitor contractor compliance with all applicable regulations and ensure that contractual requirements are met with respect to engineering design, construction, safety and environmental protection.
4.2 Pipeline Construction
4.2.1 General
Construction of the proposed pipeline will include the following major activities.
• ROW preparation; • stringing, trenching, welding, installation and backfilling; • construction of watercourse crossings; • pipeline cleaning and pressure testing; • ROW cleanup and restoration.
4.2.2 ROW Preparation
The existing EPI mainline pipeline corridor from Hardisty to the Canada-United States border near Gretna is located on flat to rolling terrain. Existing access roads required for the movement of personnel, equipment and materials are anticipated to be sufficient for the majority of the pipeline construction so that a minimal amount of temporary access will be required as part of ROW preparation.
Existing bridges will be used by construction equipment to cross watercourses wherever practical. Where necessary, temporary bridges will be installed for construction equipment. Temporary bridges will be designed, installed and removed in accordance with applicable regulations and guidelines.
Drawings identifying typical ROW configurations during construction are shown in Figure D-1 to Figure D-12 of Appendix D. The applicable locations along the pipeline route for each of the typical ROW configurations are shown in Figure D-13 of Appendix D. From Hardisty, Alberta to Cromer, Manitoba an approximate 40 m wide construction ROW will be acquired where necessary to provide a safe and efficient work space for pipeline construction activities. From Cromer, Manitoba to the Canada-United States border near Gretna, Manitoba an approximately 45 m wide construction ROW will be acquired where necessary to accommodate both the Alberta Clipper Pipeline and LSr Pipeline (part of a separate NEB Application for the Southern Lights Project) construction activities.
The objective for permanent ROW acquisition is to achieve a consistent permanent ROW width of 36.6 m along the EPI mainline pipeline corridor, except for the first 159 km downstream of Hardisty, Alberta where the objective is to achieve a consistent permanent ROW width of 43.3 m to coincide with previous ROW acquisitions.
As shown in Figure D-1, some sections of the corridor are comprised of an existing 43.3 m wide permanent ROW. For these sections, an additional permanent ROW will not be acquired.
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As shown in Figure D-2, some sections of the corridor are comprised of an existing 18.3 m wide permanent ROW. For these sections, which are adjacent to sections with an existing 43.3 m wide permanent ROW, an additional 25 m wide permanent ROW will be acquired.
As shown in Figure D-3 and Figure D-10, some sections of the corridor are comprised of an existing 36.6 m wide permanent ROW. For these sections, an additional permanent ROW will not be acquired.
As shown in Figure D-8, one section of the corridor is comprised of an existing 18.3 m wide permanent ROW with sufficient space for installation of a new pipeline. For this section, an additional permanent ROW will not be acquired.
As shown in Figure D-4, Figure D-7 and Figure D-11, some sections of the corridor are comprised of an existing 18.3 m wide permanent ROW. For these sections,which are adjacent to sections with an existing 36.6 m wide permanent ROW, an additional 18.3 m wide permanent ROW will be required.
As shown in Figure D-5, Figure D-6, Figure D-9 and Figure D-12, some sections of the pipeline route are non-contiguous to the existing EPI corridor. For these sections, a new 18 m or 26 m wide permanent ROW will be required.
Additional temporary workspace will also be acquired to facilitate specific construction activities such as crossing installations, grading and side bends. The locations for additional temporary workspace will be finalized during detailed engineering and pre-construction planning.
Grading requirements along the ROW will vary from topsoil stripping in most areas to significant grade cuts in some localized areas. Grading of the ROW will be minimized but sufficient to accommodate field pipe bending and ensure the safe movement of pipe, equipment and personnel along the ROW.
In areas of arable land, topsoil will be removed from the work area and stockpiled separately at the edge of the ROW. The topsoil will be spread back over the ROW during reclamation.
4.2.3 Stringing, Trenching, Welding, Installation and Backfilling
Dedicated crews will complete the stringing, trenching, pipe welding, installation and backfilling activities. Specialized crews will be used for construction of road, railway and watercourse crossings.
Pipe will be trucked from local stockpile sites and strung along the ROW. Pipe bending will be performed in accordance with specifications. Individual pipe joints will be lined up, clamped in place and welded. The joining program and non-destructive testing of welds will comply with the requirements of OPR-99 and CSA Z662-03.
Hydraulic excavators or trenching machines will be used to excavate the trench depending on terrain and ground conditions. The trench bottom will be inspected and any protruding rock or debris will be removed to prevent damage to pipe and coatings before lowering the pipe into the trench. In areas where blasting is required or abrasive trench materials are present, the bottom of the trench will be bedded with select or processed fine-grained backfill
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material, or the pipe will be protected with additional mechanical protection, such as rock shield, wooden lagging or concrete coating.
After installation, the pipe will be entirely covered with suitable backfill material from the trench excavation.
The length of pipe stringing and the open trench will be minimized to the extent practical, without affecting construction productivity.
Valve assemblies will be shop fabricated and tested before shipment to the site for installation.
4.2.4 Watercourse Crossing Construction
All watercourse crossings for the proposed pipeline will be constructed as described in Section 2.3.11.
Watercourse crossings will generally be constructed in sequence with spread construction and will not be constructed during restricted activity periods.
4.2.5 Pipeline Cleaning and Pressure Testing
Before pressure testing, each section of pipeline will be cleaned with scrapers to remove construction debris. This debris will be collected and disposed by following applicable regulations.
A pressure test program will be developed. All pressure tests will be performed in accordance with the requirements of OPR-99 and CSA Z662-03, and will use water as the test medium. Water for hydrostatic testing will be drawn from approved water sources and, after use, will be disposed of in accordance with all applicable regulatory requirements.
During detailed design, the feasibility of implementing an AIV as an alternative to hydrostatic pressure testing of the pipeline will be evaluated.
4.2.6 Cleanup and Reclamation
Before pressure testing, general machine cleanup will be completed along the pipeline ROW. Final cleanup, including replacing topsoil and installing erosion control measures, will be completed immediately after machine cleanup. Final cleanup may be postponed because of poor weather or unsuitable ROW conditions (but will be completed at the earliest suitable opportunity).
Water crossings will be reclaimed or restored in accordance with all applicable regulatory requirements.
The ROW will be revegetated as necessary and as soon as practical upon completion of final cleanup.
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4.3 Pumping Facilities Construction
Experienced specialized contractors will complete construction of the new pumping, tankage and terminalling facilities. It is currently planned that separate construction contractors will be retained at each of the sites, with two or more contractors at the Hardisty terminal.
With the exception of the Rowatt facility, the pumping, tankage and terminalling facilities will be constructed within existing EPI facilities sites that have experienced site disturbance and grading consistent with an industrial site. The Rowatt pump station will be constructed at a new site and will require initial site preparation and topsoil handling in accordance with the requirements contained in the ESA.
All pumps, motors and other equipment will be procured well in advance of construction and shipped to the respective pump stations or pre-fabrication sites.
4.4 Commissioning
Each completed section of the pipeline will be dewatered, and prepared for commissioning and start-up. Line filling will proceed from Hardisty to the receiving terminal at Superior, Wisconsin. A nitrogen buffer will be maintained in front of the oil as line filling proceeds.
Leave to Open documents for the pipeline will be submitted for approval by the NEB before the pipeline is put into service.
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5.0 SYSTEM OPERATIONS
5.1 General
All facilities associated with the proposed pipeline will be monitored and operated from EPI’s control centre, located near Edmonton. They will be operated in accordance with all applicable regulatory requirements, certificate conditions, licences and EPI’s own operating requirements. Field maintenance and operations staff will ensure the safe and reliable operation of the equipment and facilities in accordance with EPI’s operating and maintenance procedures and preventative maintenance program.
5.2 Pipeline Systems Control
5.2.1 General
The supervisory control and data acquisition (SCADA) system used by the operators to monitor and control EPI’s pipelines and facilities was developed and is supported by EPI staff. The SCADA system has evolved over almost 50 years and has been tested under a wide variety of operating situations. It incorporates a number of proprietary features that allow EPI to safely maximize pipeline capacity while minimizing the risk of pipeline upsets.
The computer workstations and software used at the Edmonton control centre allow operators to remotely monitor and control all elements of EPI’s pipeline systems, including the pipelines, tanks, pump stations, valves and custody transfer metering. The Edmonton control centre also monitors line pressures, flow rates, gas and fire detectors, and other safety systems.
The pipeline and facilities for the pipeline will be designed for safe operation. ESD systems can be initiated remotely or locally if any unsafe condition is detected.
Data will be made available to existing technical support locations, maintenance bases and third party locations, as defined by EPI’s operational plans.
A dedicated team of engineers, operations coordinators, supervisors and a modern in-house training centre currently support the Edmonton control centre. Pipeline controllers are trained on a computerized simulator that is programmed and customized to provide realistic simulations of the unique operating characteristics of each of EPI’s pipelines.
The Edmonton control centre has a complete backup control centre in Edmonton that is physically separated from the primary site. Operators can take full control of EPI’s pipeline systems from the backup control centre within one hour (in the event that the primary control centre becomes unavailable).
5.2.2 System Description
EPI uses a SCADA product called PROCYS, which has been developed and maintained by the company. PROCYS has a graphical user interface (GUI) integrated into the software.
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Through this interface, PROCYS allows the pipeline controller to remotely monitor and control critical aspects of EPI’s pipeline systems.
Data transmitted from selected pump stations and terminals by the SCADA system include pressures, set-points, pump and valve status, tank levels and various station alarms. This information is displayed for the pipeline controllers and monitored by PROCYS for alarms and other abnormal operating conditions. Based on the displayed information and the pumping schedule for the day, the pipeline controller can remotely control mainline and terminal equipment by adjusting pressure set-points, operating valves, initiating pump unit starts or stops, station shutdowns or complete line shutdowns.
The controller can also remotely operate block valves and mainline sectionalizing valves to safely isolate sections of a shutdown pipeline.
PROCYS provides automatic backup pressure protection through a number of subroutines. For example, the line pressure monitor (LPM) alarm system monitors the discharge pressure at one station and the suction pressure at the downstream station. The LPM can initiate set- point reductions, unit shutdowns at the upstream station, or entire line shutdowns if a section of the pipeline exceeds the operating pressure limits of sections along the pipeline.
In the event of a system shutdown because of equipment malfunctions at a pump station, the operators at the Edmonton control centre will not be able to restart the equipment until the equipment has been repaired and the trip mechanisms at the affected pump station have been manually reset.
In addition to the primary pipeline control functions, PROCYS also provides several analytical tools including a selection of pre-configured or customized graphical trends and reports. These tools are used for the analyses of normal pipeline operations and operational irregularities.
5.2.3 System Communications
The SCADA communications system incorporates redundant equipment and backup communication circuits. A combination of a wide area network (WAN) frame relay, telephone lines and satellite communication circuits provide main and backup communication systems to remote terminal units (RTUs) at all terminal, pump station and valve locations along EPI’s pipelines.
Satellite communication circuits use report-by-exception communication, in which RTUs report changes in the terminal or pump station data to the Edmonton control centre as they are detected.
Pump stations have a local ethernet network to provide an interface between local computer systems and programmable logic controllers (PLCs).
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5.2.4 Leak Detection System
EPI uses a real time transient model (RTTM) material balance system computer program for leak detection. EPI’s application of the RTTM is referred to as the MBS. This leak detection system will be used for the pipeline.
The MBS is designed to meet the current requirements of OPR-99 and CSA Z662-03 Annex E. The MBS applications reside on a dedicated high capacity UNIX server that is separate from the SCADA servers.
MBS graphics and other information are displayed on a separate computer monitor at the Edmonton control centre consoles. MBS alarms are passed to the SCADA system and appear on the SCADA monitors. Support personnel have remote access to the MBS workstations.
Alarm thresholds will be optimized during the tuning period for the pipeline. The alarm thresholds must be set as low as possible without creating nuisance alarms, which erode system credibility. The alarm thresholds are different for each pipeline because each is unique in design and operation, and the properties of the products being transported are also unique.
5.3 Regional (Field) Operations
5.3.1 General
An operations plan will be developed for the proposed pipeline. Operational policies, practices and activities will address safety and stewardship of the natural environment.
5.3.2 Operations and Maintenance Manuals
EPI has operations and maintenance manuals for the existing pipeline system and they will be the basis for the operation of the proposed pipeline. These manuals will be revised to include any new procedures as required by the pipeline. The operations and maintenance manuals include:
• general reference procedures, including topics such as regulatory compliance, incident reporting, public awareness, record keeping and training;
• safety procedures, including topics such as safe work practices, hazard assessment, confined space entry, fire protection, lock-out/tag-out, personal protective equipment, etc.;
• pipeline facility procedures, including work planning and preparation, environmental protection, ROW maintenance, foreign crossings, pipe repair and testing, tank maintenance, etc.;
• welding procedures, including welder qualification requirements;
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• petroleum quality and measurement procedures to ensure product quality and custody transfer measurement accuracy; and
• emergency response procedures, including pre-emergency preparedness, emergency response responsibilities and actions, product containment, recovery and clean up, local release control point mapping and mitigative measures.
5.3.3 Pump Station Operations
Pump stations will normally be unstaffed but will be provided with a network workstation, station controls and unit controls for use on site.
A computer-based control system will be provided at each pump station to monitor pump units, control operating pressures, valves and station safety functions. The control system will provide the ability to start-up and shutdown pumps in a controlled sequence that prevents pressure surges from exceeding the specified MOP in the pipeline.
5.4 Routine Maintenance
Maintenance centres exist along EPI’s mainline pipeline corridor. Qualified operations and maintenance personnel are deployed from these maintenance centres to service all of EPI’s pipelines and associated facilities.
Routine maintenance of EPI’s pipeline systems includes regular preventative maintenance, inspection, testing and repair of pipeline facilities. A computerized maintenance management system is used to schedule this work and to keep records of equipment maintenance and repair. All new maintainable equipment associated with the pipeline will be identified, tagged and entered into the system.
The CP systems are tested and inspected at regular intervals to ensure that they are functioning satisfactorily.
Regular airborne visual inspections are carried out along pipeline ROW to:
• detect and control encroachments onto the ROW by third parties;
• monitor watercourse crossings (including bank erosion, slope stability and depths of cover over pipelines);
• identify product releases or other operating abnormalities; and
• monitor evidence of situations or events that could threaten the integrity of the pipelines.
Vegetation is periodically cut back along the ROW and adjacent to facilities to maintain visibility during inspection patrols, facilitate access during maintenance and reduce fire risk.
Pipeline and ROW inspection, and maintenance programs are implemented along the pipeline corridor as required based on these inspections.
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5.5 Security Management
EPI has a security management program in operation for all of its pipeline systems and facilities. The security management program includes:
• security policies and procedure manuals; • regional security response plans; • security vulnerability assessments; • threat monitoring and analysis; • physical security measures; • monitoring, tracking and trending of security incidents; and • training and support of operations personnel.
Physical security measures used at facilities include perimeter fencing, intrusion alarms, surveillance systems and lighting.
EPI works with local and federal policing authorities, and industry associations to identify and monitor trends and issues.
The Project will be incorporated into the existing EPI security management program and assessment process. All existing security plans and programs will be updated to include the new facilities as appropriate. Construction of the new facilities will not negatively impact EPI’s security response plans. Any security issues identified during construction will be managed under the existing security management program.
5.6 Emergency Response Plans
A comprehensive emergency response plan is in place for all of EPI’s pipelines. The plan includes many preventive measures, such as advance education of the public regarding pipeline crossings and encroachment issues. This plan will be modified to incorporate the Alberta Clipper Pipeline.
EPI communicates regularly with stakeholders along its pipeline corridors including landowners, government agencies and emergency response officials (such as police agencies and health care providers).
The pipelines are marked at regular intervals with emergency contact information. A 24-hour emergency call centre, located in the Edmonton control centre, can respond efficiently and effectively to public concerns or emergency situations.
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6.0 SYSTEM INTEGRITY
6.1 General
Integrity management requires risk identification and assessment. EPI uses various tools to identify, assess and evaluate operational risks applicable to EPI’s pipelines and facilities. The integrity assessment results are used to prioritize maintenance activities or projects to ensure that fitness-for-purpose tolerances are maintained. The proposed pipeline will be fully integrated into EPI’s existing integrity management program.
These activities are formalized in various integrity management programs based on the type of hazard considered.
Each integrity management program uses documented policies, procedures and practices that ensure events are accurately documented, roles and responsibilities are defined, consistency is maintained, decisions are easily communicated and justified, and continuous improvement occurs.
The integrity management programs ensure the operational reliability of all system components including the mainline pipelines, stations, terminal piping and tankage. Integrity management programs also ensure compliance with regulatory requirements.
6.2 Pipeline Integrity
The primary goal of EPI’s mainline pipeline integrity program is to prevent leaks and ruptures caused by duty-related degradation of the transmission pipelines. The principal objectives of this program are listed next:
• ensure the safety of employees and the public; • protect the environment; • strive to achieve zero failures; • provide a reliable pipeline; and • maintain the system as a long-life asset.
The pipelines are monitored to identify defects that may occur, and remedial action to be undertaken, in a planned approach to ensure the objectives of the integrity management program are realized. EPI’s approach to pipeline management is based on applying mitigative measures over the life cycle of the pipeline so that a constant base integrity level is maintained. The following integrity management activities will be applied to the proposed pipeline.
6.2.1 Prevention Programs
For proposed pipelines, the risk of pipeline failure is minimized through careful planning of pipeline routing, selecting suitable construction materials, limiting operating stress through the design factor and ensuring a high quality pipeline installation. The pipeline integrity activities associated with these efforts are described next.
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6.2.1.1 Pipeline Design, Construction and Operation Reviews
Integrity personnel participate in project development teams to provide expertise regarding the integrity measures required to ensure a long-life asset based on the proposed operating regime. The product being shipped, the terrain that will be traversed, hydraulics, pressure patterns and other properties that affect pipeline deterioration are reviewed.
6.2.1.2 Development of Construction Practices and Material Specifications
The following lists construction practices and material specifications that will be addressed:
• identify cyclic fatigue through pressure monitoring programs and undertake mitigative measures to reduce cyclic fatigue;
• provide metallurgical expertise in the selection of pipeline steels and welding procedures; and
• specify protective paints, coatings, and linings that serve to protect components from corrosion.
6.2.1.3 Incorporation of Quality Assurance and Quality Control (QA/QC) Measures
The following QA/QC measures will be acted upon:
• develop non-destructive testing procedures and implementation specifications; and
• train and audit contractors and EPI personnel involved in implementation of integrity related activities.
6.2.2 Monitoring Programs
Appropriate design, construction and operational measures, combined with ongoing monitoring programs, are aimed at preventing corrosion and cracking that have the potential to cause deterioration of mainline pipelines. The following are some of the techniques that EPI uses to confirm that prevention mechanisms are intact, and to monitor the system and assess operational data.
6.2.2.1 CP
An annual pipe-to-soil survey is performed to determine the state of the pipeline coating and the level of protection being provided by the ground bed/rectifier system. In locations where rectifiers are incorporated with protective ground beds, monthly readings are taken to confirm normal operation.
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6.2.2.2 In-line Inspection
In-line inspection is used to measure the size, frequency and location of defects. Defects are analyzed and monitored through regular inspections. The inspection intervals are set based on the integration and analysis of numerous data sets.
6.2.2.3 Investigative Excavations
Investigative excavations are conducted as a result of anomalies identified by in- line inspection (the selection of a specific location is based on a direct assessment approach), or in conjunction with some other maintenance activity. Investigative excavations are used to obtain information related to soil types, water, topography, coating condition and other characteristics in order to develop a better understanding of the root cause of the pipeline defect.
6.2.2.4 Slope Stability Monitoring Program
There are no areas of slope instability that are of concern with respect to their potential effect on the pipelines along the existing EPI pipeline corridor between Edmonton and the Canada-United States border near Gretna. EPI’s routine ROW inspections will identify areas where slope instability might exist.
In the event that slope instability occurs on or near EPI’s pipeline corridor, the unstable slopes would be monitored regularly to assess the risk that future ground movements might affect the pipelines. The scope of such monitoring programs would depend on site-specific conditions, but can include instrumentation, regular visual monitoring, pipe assessments or combination of these methods. Remediation, reconstruction projects or both will be implemented to ensure the ongoing integrity of the affected pipelines.
6.2.3 Mitigation Programs
In order to manage risks posed by pipeline deterioration, defects identified through monitoring are categorized using comprehensive fitness-for-purpose criteria. Defects that do not meet acceptance levels are repaired.
Mitigative measures used by EPI can include sleeve repairs, pipe replacements, pressure reductions, rehabilitation, and/or inhibitor injections depending on the specific situation.
6.3 Facilities Integrity
EPI uses a number of facility-based integrity programs that are administered through EPI’s program coordinators, engineers and regional operations personnel. The programs are a combination of regulated activities and proactive measures to provide a continuous, safe, reliable and environmentally responsible operation. In addition to program development and implementation, regular reviews are conducted on performance data to determine if focused, short duration initiatives are warranted.
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The following programs will be applied to all of the proposed pipeline facilities:
• leak history tracking and analysis; • a flange integrity program; • an above-ground tank inspection program; • a facility piping integrity program; • a small diameter piping program; • a site containment and drainage program; and • a pressure vessel inspection program;
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7.0 DECOMMISSIONING AND ABANDONMENT
Abandonment of a pipeline is the responsibility of the company that owns the pipeline. Therefore, if a facility needs to be decommissioned or abandoned, EPI will develop decommissioning and abandonment plans in consultation with stakeholders holding an interest in the proposed abandonment work, the NEB and other regulatory authorities.
Environmental and safety issues associated with decommissioning and abandonment options, and regulatory requirements, will be considered when developing these plans. These would likely include:
• physical elements such as the physical environment, soil capability, water quality and quantity, air quality and the acoustic environment;
• biological elements such as fish and fish habitat, wetlands, vegetation, wildlife and species-at-risk; and
• socio-economic elements such as human occupancy, resource use, infrastructure and services, and accidents and malfunctions.
The decommissioning and abandonment plan would comply with the current and acceptable regulatory standards of the day. Appropriate applications would be filed (for example, Section 74 of the NEB Act ). Decommissioning or abandonment activities would be subject to examination under the NEB Act and require NEB approval.
Easement agreements also address abandonment. Generally, easement agreements indicate that upon discontinuance of EPI’s use and the exercise of its rights, EPI will restore the lands to the same condition as prior to its entry, so far as it is practical to do so.
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APPENDIX A – TABLES
Table No. Title Table A 1 Acronyms Table A 2 Enbridge Pipelines Inc. Engineering Standards and Guidelines Table A 3 Clipper Pipeline – Preliminary List of Block Valve Locations Table A 4 Clipper Pipeline – NEB Concordance Table – Engineering
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TABLE A-1: ACRONYMS
Acronym Description AIV alternative integrity validation API American Petroleum Institute CGA Canadian Gas Association Colt Colt Engineering Corporation CP cathodic protection CSA Canadian Standards Association EPI Enbridge Pipelines Inc. ESA environmental and socio economic assessment ESD emergency shutdown FBE fusion bonded epoxy (pipeline coating) GUI graphical user interface HDD horizontal directionally drilled HP horsepower LPM line pressure monitor LSr light sour blend crude oil pipeline LVP low vapour pressure (liquid) MBS material balance system MCC motor control centre Midale midale blend (one of the products in the Clipper Pipeline) MOP maximum operating pressure NEB National Energy Board NPS nominal pipe size OD outside diameter OPR 99 Onshore Pipeline Regulations 1999 PCV pressure control valve PFD process flow diagram PLC programmable logic controller QA quality assurance QC quality control ROW right of way RTTM real time transient model RTU remote terminal unit RV recreational vehicle SCADA supervisory control and data acquisition SMAW shielded metal arc welding UPS uninterruptible power supply VFD variable frequency drive WAN wide area network
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TABLE A-2: ENBRIDGE PIPELINE INC . ENGINEERING STANDARDS AND GUIDELINES
D01 101 Use of Engineering Standards Rev. January 2005 D01 102 Policy & Style for Eng Standards Rev. Sept. 01, 1999 D02 101 Design basis, Electrical Rev. Jul 20, 2006 D02 102 Design Basis Mainline Rev. Dec. 13, 2006 D02 103 Design Basis, Station and Terminal Rev. Jan 9, 2007 D02 104 Hazardous Area Classification Rev. Nov 16, 2006 D02 105 Fire Protection, Extinguishment Rev. Jan 6, 2000 D02 106 Noise and Acoustic Dampening Rev. Sep 1, 1999 D02 107 Station Manual, Protection Rev. Sept. 01, 1999 D03 101 Pipeline Corrosion Assessment Rev. Sept. 01, 1999 D03 102 Integrity Assessment, Oil Tank Rev. July 16, 2001 D03 103 Internal Inspection, Mainline Rev. Sept. 01, 1999 D03 104 Weld Inspection Rev. Sep 1, 1999 D03 105 Shop Inspection Rev. Sep 1, 1999 D04 101 Cathodic Protection Rev. Apr 20, 2006 D04 102 Painting, Coating and Lining Rev. Jul 28, 2006 D05 101 Berm Containment Rev. Jul 22, 2005 D05 102 Site Preparation, Earthwork, Grading, Road and Pavement Rev. Sep 7, 2005 D05 103 Trenches, Underground Lines Rev. Sep 1, 1999 D05 201 Foundation, Oil Storage Tank Rev. Sept. 01, 1999 D05 202 Foundation, Station and Terminal Rev. Sep 1, 1999 D05 301 Buildings, Station and Terminal Rev. Sep 1, 1999 D05 302 Laboratory, Sample & Sample Storage Buildings Rev. Sept. 01, 1999 D05 401 Platforms, Stairs and Ladders Rev. Apr 29, 2003 D06 101 Piping Design and Construction, Mainline, Dec. 13, 2006 D06 102 Piping Design, Station and Terminal Rev. Dec 13, 2006 D06 103 Crossing Design, Mainline Rev. Dec. 13, 2006 D06 104 Piping and Fittings, Steel Rev. Jun 20, 2005 D06 105 Valve, Steel Rev. Jun 15, 2000 D07 101 Pump, Main Line Rev. Jan 31, 2006 D07 102 Pump, Booster Rev. Nov. 15, 1999 D07 201 HVAC, Building, Station & Terminal Rev. Nov 15, 1999 D07 202 Heat Tracing Rev. Jan 31, 2006 D07 203 HVAC, Pipeline Maintenance Building Rev. Nov. 15, 1999 D07 301 Sump System Design Rev. Jan 31, 2006 D07 302 Flare Stacks & Pits Rev. Nov. 15, 1999 D08 101 Oil Storage Tank Rev. Nov. 15, 1999 D08 102 Oil Storage Tank Roof Rev. Nov. 15, 1999 D08 103 Oil Storage Tank, Accessories Rev. Nov. 15, 1999 D09 101 Oil Measurement, Mechanical Rev. Jul. 20, 2006
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TABLE A-2: ENBRIDGE PIPELINE INC . ENGINEERING STANDARDS AND GUIDELINES (C ONTINUED )
D09 102 Oil Measurement, Electrical Rev. Nov. 15, 1999 D09 103 Sampler Rev. Nov. 15, 1999 D10 101 Power System Design Rev. Jan 25, 2006 D10 102 Substation Design Rev. Dec. 01, 1999 D10 103 Switchgear & Motor Control Center Rev. Oct. 24, 2002 D10 104 Auxiliary Power Supplies Rev. Dec 1, 1999 D10 105 Power System Protective Relaying Rev. Jan 25, 2006 D10 106 Substation Grounding Rev. Dec. 01, 1999 D10 107 Surge Protection & Insulation Coordination Rev. Dec 1, 1999 D10 201 Wiring Methods Rev. Jul 20, 2006 D10 202 Grounding Methods Rev, Dec 1, 1999 D11 101 Motor, Mainline Pump Rev. Dec. 01 1999 D11 102 Variable Frequency Drive Rev. Dec. 13, 2006 D11 103 Motor Protection Rev. Dec. 01, 1999 D11 201 Lighting, Indoor Rev. Dec 1, 1999 D11 202 Lighting, Outdoor Rev. Dec 1, 1999 D11 301 Valve Actuation and Control Rev. Jan 11, 2007 D12 101 Control, Pump Station Rev. July 20, 2006 D12 102 Control, Injection & Delivery Facility Rev. July 20, 2006 D12 104 Pressure Relief Rev. Oct. 2, 2003 D12 201 Instrumentation, General Rev. Nov. 26, 2002 D12 202 Gas Detection Rev. Dec. 01, 1999 D12 203 Fire Detection Rev. Dec. 01, 1999 D12 204 Vibration Monitoring Rev. Dec. 01, 1999 D12 205 Programmable Logic Controllers Rev. Dec. 01, 1999 D12 208 Pressure Control System Rev. Feb. 21, 2006 Specifications for Facility Construction (Canada) Section 01 Site Preparation Rev. Mar. 14, 2003 Section 02 Piping and Electrical Rev. Mar. 14, 2003 Section 03 Sewers and Drains. Rev. Mar. 14, 2003 Section 04 Roads and Asphalt Paving Rev. Mar. 14, 2003 Section 05 Grouting Rev. Mar. 14, 2003 Section 06 Concrete Rev. Mar. 14, 2003 Section 07 Concrete Piles Rev. Mar. 14, 2003 Section 08 Steel Pipe Piles Rev. Mar. 14, 2003 Section 09 Precast Concrete Piles Rev. Mar. 14, 2003 Section 10 Electrical Rev. Mar. 14, 2003 Section 11 Instrument Rev. Mar. 14, 2003 Section 12 Station Piping Rev. Mar. 14, 2003 Section 13 Piping Classes Rev. Mar. 14, 2003
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TABLE A-2: ENBRIDGE PIPELINE INC . ENGINEERING STANDARDS AND GUIDELINES (C ONTINUED )
Section 14 Pressure Testing Facility Piping Rev. Mar. 14, 2003 Section 15 Mechanical Equipment Installation Rev. Mar. 14, 2003 Section 16 PE & PVC Pressure Piping Rev. Mar. 14, 2003 Section 17 Coatings Rev. Mar. 14, 2003 Section 18 Structural Steel Rev. Mar. 14, 2003 Section 19 Painting Rev. Mar. 14, 2003
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TABLE A-3: CLIPPER PIPELINE – PRELIMINARY LIST OF BLOCK VALVE LOCATIONS
Description Approximate Location (KP) Hardisty terminal 175.4 209.0 Metiskow station 229.6 263.6 Cactus Lake station 289.8 335.1 Kerrobert station 351.3 381.6 Herschel station 413.8 445.4 Milden station 475.3 504.2 506.7 524.0 Loreburn station 538.4 573.2 Craik station 590.7 637.4 Bethune station 652.9 657.8 R13.2a Rowatt station R39.7a 749.2 Odessa station 762.0 789.5 Glenavon station 812.1 K3.3b Langbank station 875.2 Kelso site 900.0 929.2 937.9 Cromer terminal 958.8 988.1 1009.2 West Souris station 1031.6 1045.3 1072.9 1073.9
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TABLE A-3: CLIPPER PIPELINE – PRELIMINARY LIST OF BLOCK VALVE LOCATIONS (C ONTINUED )
Description Approximate Location (KP) Glenboro station 1103.3 1131.0 St. Leon station 1155.6 1194.4 1206.4 1227.0 Gretna station 1242.4 Notes: aDenotes that the location is on the Regina re route. bDenotes that the location is on the Kipling re route.
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TABLE A-4: CLIPPER PIPELINE – NEB CONCORDANCE TABLE – ENGINEERING
In Application? Not in Application? Filing Requirement References a Explanation A.1.1 Engineering Design Details 1. Fluid type and composition. Section 2.2, Table 2 3 2. Line pipe specifications. Section 2.3.2, Table 2 5 3. Pigging facilities specifications. Section 2.3.8 Table 2 6 4. Pump facilities specifications. Sections 2.2, 3.0 Tables 2.4, 3 1 5. Pressure regulating or metering facilities specifications. Section 3.3 6. Liquid tank specifications. Section 3.3 Not included in project scope 7. New control system facilities specifications. Section 5.2 8. Gas processing, sulphur or LNG plant facilities specifications. N/A No such facilities 9. Technical description of other facilities not mentioned above. N/A No other facilities 10. Building dimensions and uses. Sections 3.4, 3.6 11. If project is a new system that is a critical source of energy N/A Not a critical energy supply supply, a description of the impact to the new system because there are other capabilities following loss of critical component. export pipelines in the same corridor A.1.2 Engineering Design Philosophy 1. Confirmation project activities will follow the requirements of Section 1.4 the latest version of CSA Z662. 2. Statement confirming compliance with OPR or PPR. Section 1.4 3. Listing of all primary codes and standards, including version Section 1.4 and date of issue. 4. Confirmation that the project will comply with company Section 1.4 manuals and confirm manuals comply with OPR/PPR and Table A 2 codes and standards. 5. Any portion of the project a non hydrocarbon commodity N/A All products are hydrocarbon pipeline system? Provide a QA program to ensure the liquids materials are appropriate for their intended service. 6. If facility subject to conditions not addressed in CSA Z662: Section 2.3.15 Written statement by qualified professional engineer. Description of the designs and measures required to safeguard the pipeline. 7. If directional drilling involved Section 2.3.11, Preliminary feasibility report Section 4.2.4 Description of the contingency plan
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TABLE A-4: CLIPPER PIPELINE – NEB CONCORDANCE TABLE – ENGINEERING (C ONTINUED )
Filing Filing Requirement In Application? Not in Application? No. References a Explanation A.1.3 Onshore Pipeline Regulations 1. Designs, specifications programs, manuals, N/A Existing standards will be followed procedures, measures or plans for which no standard is set out in the OPR 2. A quality assurance program if project non routine N/A No unique challenges or incorporates unique challenges due to geographical location 3. If welding performed on a liquid filled pipeline that N/A Will not be conducted has a carbon equivalent of 0.50% or greater and is a permanent installation: Welding specifications and procedures Results of procedure qualifications Note: aN/A=not applicable
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APPENDIX B – FIGURES
Figure No. Title B 1 Surficial Geology Map B 2 Hardisty Terminal Proposed Plot Plan Pump Facility B 3 Kerrobert Station Proposed Plot Plan B 4 Milden Station Proposed Plot Plan B 5 Craik Station Proposed Plot Plan B 6 Rowatt Station Proposed Plot Plan B 7 Glenavon Station Proposed Plot Plan B 8 Cromer Terminal Proposed Plot Plan B 9 Glenboro Station Proposed Plot Plan B 10 Gretna Station Proposed Plot Plan B 11 Hardisty Terminal Proposed Plot Plan (Tanks) B 12 Typical Process Flow Diagram – Initiating Station B 13 Typical Process Flow Diagram – Traps Configuration B 14 Typical Process Flow Diagram – Three Valve Cluster
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APPENDIX C – CLIPPER PIPELINE ROUTE MAPS
Title
Clipper Pipeline – Index to Route Maps Clipper Pipeline – Route Map 1 of 12 Clipper Pipeline – Route Map 2 of 12 Clipper Pipeline – Route Map 3 of 12 Clipper Pipeline – Route Map 4 of 12 Clipper Pipeline – Route Map 5 of 12 Clipper Pipeline – Route Map 6 of 12 Clipper Pipeline – Route Map 7 of 12 Clipper Pipeline – Route Map 8 of 12 Clipper Pipeline – Route Map 9 of 12 Clipper Pipeline – Route Map 10 of 12 Clipper Pipeline – Route Map 11 of 12 Clipper Pipeline – Route Map 12 of 12
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APPENDIX D – TYPICAL PIPELINE INSTALLATIONS AND CONSTRUCTION PROCEDURES
Figure No. Title D 1 Typical Right of Way During Construction For 2 Existing ROWs (18.3 m & 25.0 m) D 2 Typical Right of Way During Construction For 1 Existing ROW (18.3 m) & 1 New ROW (25.0 m) D 3 Typical Right of Way During Construction For 2 Existing ROWs (18.3 m & 18.3 m) D 4 Typical Right of Way During Construction For 1 Existing ROW (18.3 m) & 1 New ROW (18.3 m) D 5 Typical Right of Way During Construction For 1 New ROW (18.3 m) D 6 Typical Right of Way During Construction For 1 New ROW (18.0 m) Adjacent to Foreign ROW D 7 Typical Right of Way During Construction For 1 Existing ROW (18.3 m) & 1 New ROW (18.3 m) D 8 Typical Right of Way During Construction For 1 Existing ROW (18.3 m) D 9 Typical Right of Way During Construction For 1 New ROW (26.0 m) Adjacent to Foreign ROW D 10 Typical Right of Way During Construction For 2 Existing ROWs (18.3 m & 18.3 m) D 11 Typical Right of Way During Construction For 1 Existing ROW (18.3 m) & 1 New ROW (18.3 m) D 12 Typical Right of Way During Construction For 1 New ROW (18.0 m) D 13 Locations for Typical Right of Way Drawings D 14 Typical Minimum Trench Dimensions D 15 Typical Right of Way After Backfilling Ditch D 16 Typical Watercourse Crossing Design D 17 Typical Foreign Pipeline Crossing Design D 18 Typical Paved Road Crossing Designs D 19 Typical Gravel Surfaced Road Crossing Design D 20 Typical Railway Crossing Design D 21 Typical Block Valve Layout
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